Order of the Federal Environmental, Industrial and Nuclear Supervision Service (Rostechnadzor) No. 534 of 15 December 2020
Unofficial translation. Only the Russian original published in the official sources of the Russian Federation has legal force. This translation is provided for reference and does not replace the official document.
1. The Federal Norms and Rules in the field of industrial safety "Safety Rules in the Oil and Gas Industry" (hereinafter - the Rules) have been developed in accordance with Federal Law No. 116-FZ of 21 July 1997 "On Industrial Safety of Hazardous Production Facilities" (Collection of Legislation of the Russian Federation, 1997, No. 30, Article 3588; 2020, No. 50 (Part III), Article 8074).
2. These Rules establish requirements aimed at ensuring industrial safety, preventing accidents and incidents at hazardous production facilities of oil and gas production operations and ensuring the readiness of organisations operating hazardous production facilities of oil and gas production operations (hereinafter - the operating organisation) to contain and eliminate the consequences of accidents at hazardous production facilities: of drilling and production: of reference, parametric, prospecting, exploration, production, injection, control (piezometric, observation), special (absorbing, water-intake), iodine-bromine, balneological and other wells, which are sunk for the purpose of prospecting, exploration and development of oil, gas and gas condensate fields, coalbed methane gas, geothermal, industrial and mineral waters, and geological structures for the creation of underground storage of oil and gas, the disposal of industrial effluents and harmful production waste, as well as wells drilled to eliminate gas and oil blowouts and griffons (hereinafter - wells); of the arrangement of fields for the collection, treatment, storage and transportation of oil, gas and gas condensate; offshore facilities of oil and gas production operations; the development of oil fields by the mining method.
3. The Rules are intended for application in: the operation, design, construction, reconstruction, technical re-equipment, mothballing and decommissioning of hazardous production facilities of oil and gas production operations; the manufacture, installation, maintenance and repair of technical devices used at hazardous production facilities.
4. Fire safety requirements for hazardous production facilities are established by Federal Law No. 123-FZ of 22 July 2008 "Technical Regulations on Fire Safety Requirements" (Collection of Legislation of the Russian Federation, 2008, No. 30, Article 3579; 2018, No. 53, Article 8464).
5. The list of abbreviations used is provided in Appendix No. 1 to these Rules.
6. For all hazardous production facilities of hazard classes I, II, III, PMLA are developed in accordance with the procedure established by the Regulation on the development of action plans for the containment and elimination of the consequences of accidents at hazardous production facilities, approved by Government Resolution of the Russian Federation No. 1437 of 15 September 2020 (Collection of Legislation of the Russian Federation, 21 September 2020, No. 38, Article 5904). To ensure safety during work on the drilling, completion, reconstruction and repair of wells, contractor organisations conclude contracts with emergency rescue units for the performance of a set of works on blowout prevention safety.
7. The admission of contractor organisations to a hazardous production facility, as well as the procedure for the organisation and performance of work at a hazardous production facility, are determined by the regulation on the procedure for admission and the organisation of safe performance of work, approved by the organisation operating the hazardous production facility, and where several subdivisions of a single organisation operating the hazardous production facility are working - by the operating regulations on the organisation of safe performance of work, approved by the head of that organisation or a person authorised by them.
8. The performance of work in places where there is or may arise increased production hazard (gas-hazardous, hot and repair work) shall be carried out under a permit to work. The list of works carried out under permits to work, the procedure for issuing permits to work, as well as the lists of persons responsible for the issue and approval of permits to work and for the preparation and performance of work of increased hazard, are approved by the head of the organisation or a person authorised by them.
9. All hazardous production facilities under construction shall be provided with information boards in visible places, indicating the name of the facility and the owner and the contact telephone number. For operating facilities and facilities being commissioned that form part of a hazardous production facility, their registration numbers shall additionally be indicated in accordance with the certificate of registration of the hazardous production facility in the state register.
10. Site-type hazardous production facilities of hazard classes I, II, with the exception of linear facilities, shall have fencing, and, for the passage of people and vehicles, an access control regime or checkpoints on non-public roads leading to the specified hazardous production facilities.
11. During the period when there is no ice on the water area, an inspection of the supporting part of the hazardous production facility MNGK shall be carried out to determine the impact of ice formations on it. The frequency of inspection of the supporting part of the hazardous production facility MNGK to determine the impact of ice formations on it is established by the operating organisation, but not less than once every three years. Based on the results of the inspection, a report is drawn up, approved by the operating organisation.
12. Trawling and the dropping of anchors by vessels in the security zone of underwater pipelines shall not be permitted. The dropping of anchors in this zone may be permitted only during the performance of underwater engineering work and the repair of the pipeline where there is a written permit from the organisation operating the pipeline.
13. Before the commencement of repair work on underwater pipelines, the responsible person of the operating organisation shall familiarise themselves with the report of the inspection of the pipeline repair section by divers or robotic underwater vehicles.
14. After major repairs, an underwater pipeline is tested for strength and tightness in accordance with the requirements of the design documentation.
15. The placement of a PBU at the work site, the anchoring of support vessels and the performance of work in the security zone of power transmission lines, communication cables, offshore pipelines and other structures without written agreement with the organisation operating them shall not be permitted.
16. The stacking and storage of materials, equipment and tools in passageways, decks, working and other places of the hazardous production facility MNGK not intended for stacking and storage shall not be permitted.
17. At MSP, PBU, ME and PTK, an irreducible stock of food, drinking water and fuel and lubricants shall be maintained for the emergency supply of MSP, PBU, ME and PTK and for the life support of the people on them for a period of not less than 15 days. The volume of replenishment of the irreducible stock is determined depending on the autonomy and location of the hazardous production facility MNGK, taking into account the possibility of delivering food, drinking water and fuel and lubricants, as well as the presence of stationary desalination systems.
18. An organisation operating a hazardous production facility MNGK shall have all maps of underwater and surface communications in the work area. One copy of each map is sent to the hydrographic service.
19. Hydrometeorological information received via communication channels shall be recorded in the weather forecast log, drawn up in written or electronic form in the format established by the organisation operating the hazardous production facility MNGK.
20. In explosion-hazardous zones of the hazardous production facility MNGK, continuous monitoring of the state of the air environment is carried out. To monitor gas contamination against the PDK and the NKPR of the flame in production premises and the working zone of open outdoor installations, means of automatic continuous gas monitoring and analysis shall be provided, with an alarm that is triggered when the maximum permissible values are reached and that sends signals to the emergency protection system. In doing so, all cases of gas contamination shall be recorded by instruments with automatic recording and shall be documented.
21. The installation locations and the number of sensors for the concentration limits of flame propagation and of the PDK gas analyser sensors for harmful substances are determined by the design documentation.
22. The performance of hot work in premises and in places of possible gas accumulation outside premises may be permitted after the completion of the preparatory work and the actions provided for by the permit to work, the monitoring of the air environment with gas analysers and in the presence of the responsible person of the operating organisation specified in the permit to work.
23. At the hazardous production facility MNGK, daily records shall be kept of the people present on them and of all persons arriving and departing, regardless of the duration of their stay. The presence at the hazardous production facility MNGK of persons without the permission of the responsible person of the operating organisation shall not be permitted.
24. The person responsible for the safety of the hazardous production facility MNGK shall familiarise the persons who have arrived to carry out work (against signature in a special log) with the internal regulations, the alarm signals and the duties for specific alarms; and shall indicate the number of the cabin and the lifeboat (life raft).
25. Persons arriving at the hazardous production facility MNGK for the first time or anew shall familiarise themselves with the layout of the premises and shall proceed, accompanied by the person responsible for safety, along the evacuation routes and through the main premises of MSP, PBU, ME and PTK. The movement of first-time arrivals around the hazardous production facility MNGK without escorts and without a preliminary safety briefing shall not be permitted.
26. Organisations operating hazardous production facilities shall have available and shall ensure the functioning of instruments and systems for monitoring, automatic and remote control and regulation of technological processes, alarms and emergency automatic protection, and systems for observation, warning, communication and the support of actions in the event of an accident or incident.
27. During the performance of drilling work and the workover and major repair of wells, the organisations carrying out such work shall ensure video recording of the rotary area, with the creation of a video archive using electronic storage media.
28. The updating of the video archive is carried out not more frequently than every 30 calendar days. Where accidents and incidents are video recorded, the video archive is updated upon completion of the investigations into their causes.
29. Organisations operating hazardous production facilities shall ensure the availability, preservation and serviceability of SIZ, emergency alarms and means of monitoring gas contamination in premises and open areas where the formation of harmful or combustible substances or toxic gases in the air of the working zone is possible.
30. The arrangement of the fencing and the location of the checkpoints, as well as their layout, shall ensure the possibility of the prompt emergency evacuation of workers under various wind directions.
31. Where equipment, including in a corrosion-resistant design, is used in technological processes, measures for protection against corrosion, wear and ageing shall be developed and applied.
32. For each technological process at facilities for the production, collection and treatment of oil, gas and gas condensate, process operating regulations shall be drawn up by the design (or operating) organisation. The procedure for preparing the TR is set out in Chapter LVII of these Rules. Process operating regulations may be developed for a hazardous production facility as a whole or for a group of hazardous production facilities if they are a constituent part of a single technological complex.
33. The operating organisation shall develop an instruction on the prevention of GNVP and open blowouts that takes into account the specifics of field operation and the technology for carrying out work during the drilling, completion, geophysical surveys of wells, reconstruction, repair, technical re-equipment, mothballing and decommissioning of wells, as well as during geophysical work and PVR at wells, and shall agree it with the PASF.
34. The development of oil, gas and gas condensate fields is carried out in accordance with the requirements of the legislation on subsoil, on the basis of the technical design for the development of mineral deposits and other design documentation for the performance of work related to the use of subsoil plots, by types of minerals and types of subsoil use, as well as the requirements of these Rules.
35. The design documentation for hazardous production facilities for the arrangement of oil and gas fields is developed on the basis of the technical designs for field development in accordance with the requirements of the Town Planning Code of the Russian Federation.
36. The documentation on the arrangement of oil, gas and gas condensate fields includes organisational and engineering solutions: for the prevention of depressurisation of equipment and releases of hazardous substances in quantities that create a threat to workers and the environment; for the installation of systems for monitoring the chemical situation and for the detection of explosive concentrations of hazardous substances; for the prevention of the development and the containment of accidents associated with releases (discharges) of hazardous substances and gas-dynamic phenomena (sudden gas outbursts); for ensuring the safety of workers; for the installation of systems for automatic regulation, interlocks, alarms and the trouble-free shutdown of production processes; for ensuring the accident-resistant stability of the points and systems for controlling production processes, the safety of the workers in them and the possibility of controlling the processes during accidents; for the creation of backup sources of power supply, ventilation and water supply, communication systems and materials for eliminating the consequences of accidents at the facility; for systems of physical protection and security of the hazardous production facility against outside interference, and the arrangement and location of checkpoints, which shall ensure the possibility of the prompt emergency evacuation of workers under various wind directions, as well as for accident warning systems; for ensuring the unimpeded entry and movement of emergency rescue services and units at the facility; and calculations of the levels of possible emergency situations, including indicators of the explosion and fire hazard and the toxicity of the facility.
37. The location of the facilities for the arrangement of oil, gas and gas condensate fields is determined taking into account the requirements contained in Appendices No. 2 and No. 3 to these Rules. The smallest distances to detached rotational, residential and public buildings (with the exception of the buildings of clubs, schools, children's nursery-kindergartens and hospitals) specified in Appendix No. 2 to these Rules may be adopted as 50 per cent less, provided that the organisational and technical actions provided for by the safety justification of the hazardous production facility are implemented, with the operating conditions reflected in the design documentation.
38. The documentation for the mothballing or decommissioning of a hazardous production facility provides for actions to prevent accidents and to contain and eliminate their consequences both during the process of mothballing or decommissioning of the facility and upon completion of its mothballing.
39. Facilities for the arrangement of fields shall include: automation of the facilities that eliminates the need for the constant presence of workers at the facility and ensures the completeness of the collection of information about its operation at the process control points; a multi-level system of interlocks and safety devices that are triggered when emergency situations arise; a sealed system for the collection and transportation of the product with full use of the oil, gas and associated components and their recovery from points of emergency leaks; the necessary technical means and an autonomous system of emergency communication and warning that ensure the prompt informing of the workers of the hazardous production facility and the population about possible danger; the necessary technical means of an automated system for monitoring the air environment to ensure safe working conditions and the early detection of possible emergency releases; and the provision to those working in hazardous zones of individual gas analysers (gas detectors, dosimeters) for monitoring the air environment of the working zone, and of individual and collective means of protection against harmful substances.
40. For each of the main organisational and technical solutions aimed at ensuring the safety of workers for the period of possible accidents, the specific types and number of the necessary instruments, materials and equipment, as well as the places and special structures for their placement, operation and maintenance, shall be justified and determined in the documentation.
41. It shall not be permitted to place oil and gas treatment installations on low-lying and other sections of the terrain, in areas with prevailing winds at a speed of up to 1 m/s, inversions and fogs (more than 30 - 40 per cent per year, more than 50 - 60 per cent of days during the winter).
42. Buildings and structures with production processes that release harmful and (or) combustible substances into the atmosphere, as well as those that include sources of possible emergency releases of these substances, shall be located on production sites predominantly on the leeward side of other buildings and structures, taking into account the wind rose of the prevailing direction.
43. Where a building has two or more evacuation exits, one of them may be provided through premises that have no sources of possible release of harmful substances into the atmosphere, in which engineering equipment for servicing the specified premises is located and in which the constant presence of people is excluded, if the distance from the most remote point of the premises to the evacuation exit from it does not exceed 25 m.
44. For buildings and premises that have no sources of possible release of harmful substances into the atmosphere, as well as outdoor installations located on the territory of industrial sites that have no such sources, one evacuation exit may be provided.
45. The laying of buried channels and tunnels (with the exception of those subject to subsequent backfilling) for the placement of cables in premises and on the territory of outdoor installations that have sources of possible release into the atmosphere of harmful substances with a relative density in air of more than 0.8, as well as sources of possible spills of combustible liquids and liquids containing hydrogen sulphide, shall not be permitted.
46. The joint laying in buried tunnels and channels of steam and hot water pipelines together with pipelines for combustible and toxic substances, including the pipelines of systems for the collection and recovery of liquids containing hydrogen sulphide, shall not be permitted.
47. The construction of basements, tunnels and channels in buildings and on the territory of outdoor installations in which the release of harmful substances into the atmosphere and the formation of spills of toxic liquids are possible shall not be permitted.
48. Technological equipment and pipelines intended for operation under conditions of contact with aggressive and corrosive substances shall be equipped with instruments or devices for monitoring corrosion and corrosion cracking.
49. In technological equipment and pipelines there shall be a sealed, closed drainage system for the complete draining of toxic and explosion- and fire-hazardous liquids (including tanks for their neutralisation and supply lines to thermal neutralisation installations, or up to the installation for injecting these substances into absorbing wells).
50. The storage of toxic liquids shall be carried out predominantly in sealed underground tanks with a gas-dynamic operating regime. The storage of the specified liquids in above-ground tanks with "nitrogen" breathing may be permitted, whereby the tanks shall be equipped with an alarm for the maximum upper filling level, interlocked with the pumping equipment, and with a system for the emergency draining of excess liquid into the drainage system.
51. The storage of toxic liquids in tanks with "atmospheric" breathing shall not be permitted.
52. The underground laying of pipelines with toxic substances shall not be permitted, with the exception of the sections from the inlet and outlet manifolds to the fencing.
53. The placement of utility networks with toxic liquids and gases under buildings and structures shall be prohibited.
54. It shall be prohibited to place above-ground utility networks with toxic liquids and gases in open trays and trenches at elevations below the planning elevations of the sites, and in channels and tunnels of the semi-buried type.
55. The placement of overhead networks of transit in-site pipelines with toxic liquids along the walls and roofs of buildings, regardless of the degree of their fire resistance, shall not be permitted.
56. The crossing of pipelines with toxic liquids and gases with railway access tracks shall not be permitted, with the exception of product pipelines to double-sided loading and unloading railway racks.
57. Production buildings and the territories of installations shall be equipped with industrial sewerage and (or) surface runoff systems for the drainage of industrial effluents, groundwater and stormwater.
58. To avoid gas contamination of the territory, hydraulic seals located in wells shall be installed on it. The layer of water forming the seal shall have a height of not less than 0.25 m.
59. The emergency protection systems of explosion-hazardous technological processes shall ensure the prevention of the formation of an explosive environment in the technological equipment under all possible modes of its operation, as well as the safe shutdown of production during possible emergency situations.
60. Equipment, measuring instruments and automation systems, and lighting, alarm and communication devices intended for use in explosion-hazardous zones shall be provided in an explosion-proof design and shall have a level of protection corresponding to the class of the explosion-hazardous zone and a type of explosion protection corresponding to the categories and groups of explosive mixtures.
61. The classification of explosion-hazardous zones of premises and open spaces is carried out in accordance with the requirements of paragraphs 147 - 152 of these Rules.
62. Solutions involving the use of inert gases to displace combustible vapours and gases shall regulate the methods and shall define the means for monitoring the oxygen content and preventing the formation of its hazardous concentrations in technological media.
63. During the design of a hazardous production facility, measures for protection against static electricity shall be taken.
64. The use of production pipelines to reduce the total resistance of earth electrodes shall not be permitted.
65. To protect against the secondary manifestations of lightning and discharges of static electricity, all metal apparatus, tanks, oil pipelines, gas pipelines, product pipelines, loading and unloading devices and ventilation systems located both inside premises and outside them shall be connected to the earthing loop.
66. Separately installed technical devices, apparatus and tanks shall have their own earth electrodes or be connected to the common earthing loop. The series connection of several apparatus or tanks by an earthing conductor shall be prohibited.
67. Racks for pipelines shall, every 200 - 300 m as well as at the beginning and at the end, be electrically connected to the pipelines running along them and earthed.
68. Hazardous production facilities in the prospecting, exploration, production and arrangement of oil, gas and gas condensate fields containing hydrogen sulphide and other harmful substances shall be identified by the hazard classes of possible releases and leaks of vapours and gases into the atmosphere. For such hazardous production facilities, the following shall be established: the possibility of the formation at the facilities (including during emergency situations) of gas-contaminated zones with a concentration of harmful substances exceeding the maximum permissible sanitary norms; the boundaries of these zones, as well as local areas with a hazardous concentration of hydrogen sulphide; the possibility and intensity of SKR of the metal of equipment and technical means in contact with the aggressive environment, taking into account the parameters and criteria given in Tables No. 1 and No. 2 of Appendix No. 4 to these Rules; and the necessary actions and the level of protection when carrying out work under conditions of potential and actual threats to the safety of workers.
69. At high concentrations (over 6 per cent (by volume) of hydrogen sulphide in formation fluids, facilities for the arrangement of fields shall comply with the requirements of Chapters XLVII - LVI of these Rules.
70. For explosion- and fire-hazardous technological systems, technical devices and pipelines that are subject to vibration during operation, the operational documentation shall provide for measures to reduce it and to preclude the possibility of emergency displacement, shift, depressurisation and destruction of their assemblies and parts.
71. In organisations that have underground communications (for example, cable lines, oil pipelines, gas pipelines), diagrams of the actual location of these communications shall be approved by the head of the organisation or a person authorised by them. The revision of the diagrams of the actual location of the communications is carried out in the event of their change (the commissioning of new ones, reconstruction, decommissioning). Underground communications are marked on the ground with markers placed along the route and at turning points.
72. A PT is a linear facility (structure) with a set of technical devices on it for the transportation of gaseous and liquid media (hereinafter - the transported media) under the action of head (pressure difference) from the wells to the shut-off valves installed at the inlet of the pipeline to the process site (for example, DNS, KS, TsPS, PSP, UPN) or at the outlet from the process site, up to the facilities of the main transportation of oil and gas, unless otherwise provided for by the internal documents of the operating organisation or by approved diagrams for the delimitation of areas of responsibility.
73. The following are classified as PT: (a) for oil and oil-and-gas fields: flowlines from oil wells for the transportation of well products to metering units, including those located on well cluster sites; oil-and-gas gathering pipelines for the transportation of the products of oil wells from metering units to the additional works units of DNS and UPSV (oil-and-gas pipelines); gas pipelines for the transportation of petroleum gas from the territories of the sites where oil separation installations are located to gas treatment installations, preliminary treatment installations or to consumers; oil pipelines for the transportation of gas-saturated or degassed watered or water-free oil from the oil collection point and DNS to the TsPS; gas pipelines for the transportation of gas to production wells under the gas-lift production method; gas pipelines for the supply of gas into productive formations for the purpose of enhancing oil recovery; pipelines of oil formation waterflooding systems and systems for the disposal of formation and waste waters into deep absorbing horizons, including those located on well cluster sites; oil pipelines for the transportation of commercial oil from the TsPS to the main transport structure; gas pipelines for the transportation of gas from the TsPS to the gas main transport structure; inhibitor pipelines for the supply of inhibitors to wells or other facilities for the arrangement of oil and oil-and-gas fields; demulsifier pipelines for the supply of demulsifier to the DNS and UPSV facilities; gas pipelines from UKPG/UPPG to the gas processing plant and (or) the SPG plant; condensate pipelines from UKPG/UPPG to the gas processing plant and (or) the SPG plant; inhibitor pipelines from the inhibitor storage warehouses to UKPG/UPPG; inter-field pipelines; (b) for PKhG - pipelines between the sites of individual PKhG facilities; (c) for gas, gas condensate and oil-gas-condensate fields: gas gathering lines from single wells or from each well of a cluster to the inlet valve at the field site or the gathering point (up to the switching valve buildings or the slurry treatment installations); gas gathering headers from the tie-in of gas wells; pipelines for stable and unstable gas condensate; pipelines for the supply of purified gas and inhibitor into wells and to other facilities for the arrangement of fields; waste water pipelines with a pressure of more than 10 MPa for the supply of water into wells for injection into absorbing formations, including those located on well cluster sites; methanol pipelines; oil-gas-condensate pipelines. These Rules do not apply to: pipelines for main transport; pipelines for the transportation of products with a temperature above 100 °C; gas pipelines of gas distribution and gas consumption networks; technological in-site pipelines, including inhibitor pipelines, methanol pipelines and demulsifier pipelines from chemical reagent supply units; kill lines and flare discharge lines.
74. Regardless of the method of laying (underground, above-ground, overhead), the reliable and safe operation of the PT shall be ensured, taking into account the terrain and the soil and natural-climatic conditions.
75. Technical solutions shall ensure the compensation of movements of the PT caused by changes in temperature and the action of internal pressure.
76. The means used for protection against possible types of corrosion shall ensure the trouble-free (as regards corrosion) functioning of the PT in accordance with the conditions and service life established by the design documentation (documentation). The methods and means of anti-corrosion protection shall ensure protection against external (atmospheric) and underground corrosion, corrosion by stray and induced currents, and internal corrosion (inhibitor protection, internal protective coatings, corrosion-resistant steels).
77. The technological processes for cleaning the cavity of the PT and diagnostic work shall ensure the safe operation of the PT.
78. The use of threaded connections on the PT shall be prohibited, with the exception of technical devices forming part of the PT (for example, media separators, KIPiA).
79. The design documentation may provide for the use of non-metallic pipes and their connections.
80. Facilities for the collection, treatment and transportation of oil, gas and gas condensate are equipped with: alarms for monitoring the explosive concentration of gas; a system for automatic monitoring of the position of the liquid level and the pressure in separators, settling tanks and tanks; a system of linear shut-off devices or other automated shut-off valves with autonomous and remote control.
81. Enclosed premises of facilities for the production, collection and treatment of oil and gas (drilling rigs, metering, collection and treatment points, KS) shall be equipped with working and emergency ventilation, with the output to the TsPU of the main technological parameters and the readings of the state of the air environment at the facility.
82. At control facilities, signal devices for warning of the shutdown of facilities and feedback with the TsPU shall be provided.
83. For each facility controlled from the TsPU, an interlock system and manual control directly at the facility shall be provided.
84. Discharges from safety valves on technological equipment, as well as from communications, are directed into a tank (droplet separator), and the gas - to a flare or a dispersion stack.
85. Purging, depressurisation and pumping-through of utility lines shall be carried out with subsequent separation and utilisation of the liquid and gas.
86. Where process pipelines carrying gas, LVZh or GZh cross pipelines carrying non-combustible substances, the latter are positioned underneath.
87. Risers of the flow and air lines shall be attached to the steel structures of the MSP, PBU, PTK and ME by clamps. Air and flow lines shall not be located on walkways, working platforms and other crossings over utility lines.
88. For safe inspection and maintenance of the above-water elements of the MSP, PBU, ME and PTK, hatches, passages, stairways, railings and special inspection devices are provided.
89. To enable simultaneous drilling of new wells and operation of wells in service, the wellheads of wells whose drilling has been completed are positioned on the lower tier (level) of the MSP, while during drilling the wellheads and the PVO are positioned on the upper tier (level) of the MSP.
90. For hazardous production facilities of the MNGK, actions are developed to prevent emergency releases and discharges of oil, oil products and other hydrocarbons (in liquid and gaseous phase) into the environment.
91. On the MSP, ME, PBU and PTK, special containers are installed for collecting spent drilling mud and cuttings from cleaning of the drilling mud. At the location of the containers, drip trays are installed or a sealed enclosure is provided with drainage of the liquid into the common wastewater collection system.
92. Drip trays and sealed enclosures installed on hazardous production facilities of the MNGK near the wellheads, beneath process equipment and other technical devices, are connected to the common wastewater collection system and are provided with approaches and gangways.
93. Gas released during purging and depressurisation of wells that have been put into operation, of flow lines and of vessels operating under pressure is utilised. Where utilisation is not possible, the gas is directed to a flare, ensuring that its thermal impact does not exceed the values permissible for workers and process equipment. The flare stack is located on the leeward side of the accommodation block, taking account of the prevailing wind direction.
94. Pumping of product from one tank to another is ensured by their interconnecting piping.
95. At the beginning and end of a subsea pipeline for the transport of oil and gas, automatic shut-off devices are installed for its isolation in emergency situations. Subsea pipelines are divided into sections, between which automatic shut-off devices are installed.
96. On the MSP, ME and PBU, emergency and audible-visual alarm systems shall be provided.
97. To enable construction, reconstruction, capital repair, technical re-equipment, mothballing and decommissioning, the organisation operating the hazardous production facility: transfers to the contractor, for the performance of the work, the design documentation for construction or reconstruction approved by it, or the documentation for capital repair, technical re-equipment, mothballing or decommissioning, to the extent necessary for the performance of the work of the contractor and of the engaged organisations; checks the availability of the necessary permit documents from the persons performing the work; of equipment and materials; ensures control of the presence of documents confirming the conformity of the technical devices and materials used; ensures quality control of the technical devices and materials used; ensures that construction and production control of the performance of the work by the contractors and engaged organisations is carried out.
98. Upon completion of the construction and installation work, the hazardous production facility is put into operation. For commissioning work involving hazardous substances or in explosive conditions, process regulations specifying safety measures shall be developed.
99. To ensure the quality of structures, products and materials at all stages of the work during construction, reconstruction, technical re-equipment and capital repair of the PT, incoming inspection of materials and equipment shall be organised, as well as quality control of the performance of the work and of all process operations. The results of the inspection shall be documented.
100. If deviations from the requirements of the design documentation (documentation) are detected, if facts of the use of materials not provided for by the design documentation are revealed, or if breaches of the procedure and quality of the performance of the work are found, the construction and installation work shall be suspended and the detected defects shall be eliminated.
101. The need for, and the timing and methods of performing the work on reconstruction, technical re-equipment and capital repair of the PT, shall be determined on the basis of the conditions for ensuring safe operation of the PT and the requirements of industrial safety.
102. Decisions on the timing, methods and scope of performing the work on reconstruction, technical re-equipment and capital repair of the PT shall be taken having regard to the analysis of the survey results and the service life of the PT.
103. The performance of the work on reconstruction, technical re-equipment and capital repair shall begin after the preparatory actions have been completed, the facilities have been accepted by the person performing the work, and written authorisation for the performance of the work has been given by the management of the operating organisation.
104. Before commencing the work on reconstruction, technical re-equipment and capital repair of the PT, the performing authorities shall notify the organisations (owners) operating structures that run in the same technical corridor as the PT, and also the local self-government bodies, of the commencement and timing of the work, where such work is carried out on the territory, or the protective zone of the facilities under construction extends onto the territory, of populated areas.
105. Upon completion of reconstruction, technical re-equipment and capital repair, PT facilities shall, where sections of the PT are replaced, be tested for strength and leak-tightness in accordance with the requirements of the design documentation (documentation). Where repair work not involving replacement of sections of the PT is carried out, the need for strength tests and the leak-tightness check are determined by the documentation for the performance of such work.
106. In hydraulic strength tests and leak-tightness checks, test media (water and other non-combustible liquids) shall be used, and in pneumatic tests, gaseous media (air, inert gas). The use of gaseous working media shall be justified in the design documentation for the performance of the tests.
107. At negative ambient temperatures, or where it is not possible to provide the necessary quantity of test medium for hydraulic tests, strength and leak-tightness tests of the PT may be carried out with gaseous media, in which case the requirements of paragraph 906 of these Rules shall be taken into account. The method of performing the test shall be justified by the design documentation.
108. Upon completion of the construction, reconstruction, technical re-equipment, capital repair, strength test and leak-tightness check of the PT, a comprehensive trial shall be carried out. Filling of the PT with the transported medium and its operation after filling for 72 hours are considered to be the comprehensive trial of the PT. The filling and comprehensive trial shall be carried out in accordance with the action plan established by the design documentation.
109. Before the commencement of commissioning work and comprehensive trial work, the operating organisation shall be staffed with certified workers of appropriate qualification in accordance with the staffing schedule.
110. The putting into operation of newly constructed PT, and of sections of the PT replaced during reconstruction, technical re-equipment and capital repair, shall be carried out in accordance with the design documentation.
111. When putting into operation a newly constructed PT whose route runs in the same technical corridor as other utility lines, the operating organisation shall, jointly with the owners of the other utility lines and structures of the technical corridor, develop a regulation (instruction) on the conditions for joint operation of the linear structures.
112. Continuous radiotelephone communication, and also communication with the hydrometeorological service, is provided between the floating craft engaged in work on the subsea pipelines and the shore base.
113. During the performance of work on a subsea pipeline, control over the timely and regular receipt of weather forecast information is exercised by the responsible person of the operating organisation.
114. On a subsea pipeline and at the points where it comes ashore, the use of pipes with damaged anti-corrosion or concrete coating shall not be permitted.
115. Production risers shall be secured to the structure of the stationary platforms.
116. Before being commissioned, pipelines are subjected to external inspection and to strength and leak-tightness testing. The type of test and the values of the test pressures of the pipeline are determined during design.
117. External inspection of subsea pipelines is carried out during their lowering under water.
118. Testing of a subsea pipeline is carried out in accordance with an instruction setting out the procedure for performing this work and the safety measures. The instruction is drawn up jointly by the construction organisation and the operating organisation and is approved by the operating organisation. Strength testing and the leak-tightness check of the subsea pipeline are carried out after the completion of all construction and installation work on it.
119. Based on the results of the strength and leak-tightness testing of the pipeline, a report is drawn up in the form approved by the operating organisation.
120. A pipeline is put into operation after completion of the work provided for by the design documentation, where means of electrochemical protection and devices for control, automation and telemechanics are available.
121. After completion of the work and testing, the subsea pipeline is subjected to a check along its entire route. A repeat check of the subsea pipeline is carried out within a period no later than one year from the start of operation; subsequent checks are carried out at a frequency determined during design, but no less frequently than once every 8 years. The scope and methods of the checks are determined during the design of the pipelines. A check of the pipeline by the method of underwater video monitoring, including in a backfilled trench, for the detection of oil or gas leaks and contamination of the seabed surface, is mandatory.
122. In cases where environmental conditions create a threat to the safety of the performance of the work or adversely affect its quality, the organisation directly carrying out the construction, operation, reconstruction, capital repair, technical re-equipment, mothballing and decommissioning of the subsea pipeline shall suspend the work until favourable weather conditions arise under which this work may be continued.
123. Acceptance of hazardous production facilities of the MNGK, or of their components, on which construction, installation and commissioning work at the operation site has been completed, is carried out by a commission appointed by an order of the operating organisation, with the drawing-up of an acceptance report approved by the head of the operating organisation, provided that the following are available: reports of the acceptance (periodic) tests of the main and auxiliary equipment; documents confirming the conformity of the technical devices with the requirements of industrial safety; workers holding the appropriate qualification, certification in the field of industrial safety and documents entitling them to work in marine conditions.
124. For explosion- and fire-hazardous processes, emergency protection and gas safety systems shall be used that ensure safe shutdown or transfer of the process to a safe state in the event of a critical deviation from the parameters provided for by the process regulations.
125. The start-up of technical devices newly installed after capital repair or repair involving structural changes is carried out where the results of the acceptance tests are positive. The results of the acceptance tests are documented by a report of the operating organisation.
126. The operation of a technical device whose working parameters do not ensure the safety of the process shall not be permitted.
127. When starting up or shutting down technical devices and process systems, measures shall be provided to prevent the formation in them of explosive mixtures and of plugs formed as a result of hydrate formation or freezing of liquids.
128. The operation of technical devices and tools in a defective condition, or with defective safety devices (interlocking, locking and signalling appliances and instruments), and also with deviation from the working parameters established by the manufacturer, shall not be permitted. Further operation is permitted after the identified deficiencies have been eliminated.
129. Upon reaching the service life established by the manufacturer, further operation of a technical device after the expiry of the service life shall not be permitted.
130. The criteria for limit states and the criteria for withdrawal from operation are determined by the manufacturer and are entered into the operational documentation of the manufacturer or developer of the technical device.
131. Extension of the safe operation period of technical devices after the expiry of the service life shall be carried out based on the results of an industrial safety expert review.
132. The electrical equipment of a hazardous production facility shall be resistant to environmental effects or protected from such effects.
133. The cells of the switchgear of a hazardous production facility rated for a voltage of 6 kV shall be equipped with a locking device and an interlock precluding the possibility of: performing operations with the disconnector when the oil, vacuum or electric-gas circuit-breakers or the high-voltage contactor are switched on; switching on the disconnector when the rear door of the cell is open; opening the rear door when the disconnector is switched on.
134. The horizontal distance from the outermost conductor of an overhead LEP with a voltage of 6-10 kV (at its maximum deflection) to the pump room, amenity and other structures shall comply with the requirements of electrical safety.
135. Intersection of the vertical plane passing through the outermost conductors of overhead LEPs with the guy wires of derricks shall not be permitted.
136. To ensure the safety of persons, the exposed conductive parts of electrical installations (the conductive parts of an electrical installation accessible to touch, not normally live but which may become live in the event of damage to the basic insulation), the enclosures of electrical installations (electrical equipment) and the enclosures of the drive equipment shall be earthed (neutralised) and constructed in accordance with the requirements of this Chapter.
137. To determine the technical condition of an earthing device, the following shall be carried out: measurement of the resistance of the earthing device; measurement of the touch voltage (in electrical installations whose earthing device is designed according to the standards for touch voltage), a check of the presence of a circuit between the earthing device and the elements being earthed, and also of the connections of the natural earth electrodes with the earthing device; measurement of the short-circuit currents of the electrical installation, a check of the condition of the breakdown fuses; measurement of the resistivity of the soil in the area of the earthing device. The measurements shall be performed during the period of maximum drying of the soil (for permafrost areas - during the period of maximum freezing of the soil) no less than once a year. A check of the "phase-neutral" circuit in electrical installations up to 1 kV with a solidly earthed neutral (with the drawing-up of a test protocol) shall also be carried out. The results of the measurements are documented by protocols.
138. Repair of technical devices with an electric-motor drive is carried out only after measures have been taken that preclude the possibility of accidental switching-on of the electric drive.
139. Admission to work on a switching device is permitted after technical actions ensuring the safety of the work have been carried out, including actions preventing the erroneous operation of the switching device.
140. Hazardous production facilities shall be provided with portable luminaires. To power portable (hand) electric luminaires in rooms of increased danger and in especially dangerous rooms, a voltage no higher than 50 V shall be used, and for work in especially unfavourable conditions and in outdoor installations - no higher than 12 V.
141. The list of rooms of increased danger, especially dangerous rooms, and also especially unfavourable conditions is determined, on the basis of the design documentation, by an organisational and administrative document of the organisation for each structural subdivision.
142. The plugs of instruments rated for a voltage of 12-50 V shall not fit into sockets with a higher rated voltage.
143. In rooms where a voltage of two or more ratings is used, all plug sockets shall bear inscriptions indicating the rated voltage.
144. A singly installed technical device shall have its own earthing devices or be connected to the common earthing device of the installation by means of separate earthing conductors.
145. The series connection of several objects being earthed into an earthing device (the interconnection of the earthing devices of different buildings, structures and installations by means of a single earthing conductor) shall be prohibited.
146. The installation, dismantling and adjustment of surface power electrical equipment, the power supply, lighting, lightning protection and earthing systems shall be performed by workers holding admission to the maintenance and repair of electrical equipment. Requirements for ensuring explosion safety. Organisational and technical requirements
147. The selection of electrical equipment and electrical apparatus for a hazardous production facility shall be guided by the classification of explosion-hazardous zones.
148. Any enclosed rooms that communicate with zones of classes 0 and 1 are considered to be explosion-hazardous. Their explosion-hazard class corresponds to the explosion-hazard class of the communicating zone.
149. The class and boundaries of explosion-hazardous zones around the sources of formation of explosive mixtures are set out in Appendix No. 5 to these Rules. The dimensions of explosion-hazardous zones are determined during design, taking account of the features of the process, the characteristics of the hazardous substances, the ventilation systems and other factors affecting the intensity of possible leaks and the spread of gas-air and vapour-air mixtures.
150. Electrical equipment (machines, apparatus, devices), measuring instruments and automation systems, electric luminaires, interlocking devices, telephones and their signalling devices installed in explosion-hazardous zones of classes 0, 1 and 2 shall be of explosion-proof design.
151. For each type of explosion-proof electrical equipment of domestic and foreign manufacture, documents shall be drawn up on the assessment (confirmation) of its conformity with the requirements established by regulatory documents, under the conditions of its operation in an explosion-hazardous zone.
152. The operation of electrical equipment with defective explosion-protection devices, interlocks, or with breaches of the control and protection circuits is not permitted.
153. On the MSP, ME, PPBU, PTK and SPBU, explosion-hazardous zones are designated.
154. The rooms and spaces classified as explosion-hazardous zones of the MSP, ME, PPBU, PTK and SPBU are specified in Appendix No. 5 to these Rules.
155. The installation of electrical equipment not bearing explosion-protection marking in explosion-hazardous zones of explosion-hazard classes (hereinafter referred to as zones) 0, 1 and 2 shall not be permitted.
156. The provision of openings (doors, windows) between rooms with zones 1 and 0 shall not be permitted.
157. An enclosed room directly communicating with a room with zone 0 is classified as a room with zone 1 under the following conditions: access is provided through self-closing gas-tight doors opening towards the space of zone 1; the ventilation provides overpressure relative to zone 0; an alarm is provided at the control post with a permanent watch, activated when the ventilation ceases to operate.
158. An enclosed room directly communicating with zone 0 is considered explosion-safe under the following conditions: access is provided through double self-closing gas-tight doors forming an air lock in which air pressurisation is created by mechanical supply ventilation; the ventilation provides overpressure relative to the explosion-hazardous space; an alarm is provided in the control post with a permanent watch, activated when the ventilation ceases to operate.
159. Rooms in which only sections of pipelines for flammable and combustible liquids that have no connecting flanges are laid are classified as explosion-safe, provided that the pipes are laid through the walls in sleeves having seals that preclude the ingress of explosive mixtures into the rooms.
160. An enclosed room directly communicating with zone 1 is considered explosion-safe under the following conditions: access is provided through self-closing gas-tight doors opening into a safe zone; the ventilation provides overpressure relative to the explosion-hazardous space; an alarm is provided at the control post with a permanent watch, activated when the ventilation ceases to operate.
161. In the zones, the storage of used rags and wiping materials shall not be permitted.
162. The air exchange rate in rooms with zones shall be no less than 6 per hour, and in emergency mode a no less than 8-fold air exchange per hour by the full internal volume of the rooms shall be ensured.
163. Sensors monitoring the concentration limits of flame propagation shall be installed: at the points of air intake for ventilation of the rooms of hazardous production facilities of the MNGK; at each pump pumping LVZh; in the room in which the pumps for pumping drilling mud are installed; in the area of the wellhead at a height of no more than 0.5 m above the floor; above the open drilling-mud tank - at a distance of no more than 0.2 m above its upper edge, and also next to the tank at a height of 0.5 m above the floor; at the shale shaker - at a distance of no more than 1 m from it, at a height of no more than 0.5 m above it; at the process apparatus - at the locations of possible sources of emissions of vapours and gases, at a height of no more than 0.5-0.7 m above the source for petroleum gases and at a height of 0.5 m above the floor for oil vapours; at the section of the gas-distribution batteries - at no less than two points in the room, at a height of no more than 0.5-0.7 m above the source; in storage rooms for the storage of LVZh and combustible gases - no less than one per room; under the working platform of the drilling rig - in the area of the drilling-mud flow diverter, at a distance of no more than 1 m from it; at each air intake of the diesel generators; inside the ice protection of the drilling riser (where present); in the unit for the preparation, storage and treatment of drilling mud, at a height of no more than 0.5 m above the floor.
164. Sensors of the gas analysers for the PDK of hydrogen sulphide are installed under the working platform of the drilling rig (in the area of the flow diversion) and in rooms where the release of hydrogen sulphide is possible.
165. On hazardous production facilities of the MNGK, uninterrupted power supply is provided. The power installations of hazardous production facilities of the MNGK shall provide: power supply to consumers during the drilling, production, treatment and transport of oil and gas (the main power installation); the possibility of standby supply of electricity to consumers during the drilling, production, treatment and transport of oil and gas (the auxiliary power installation); power supply to consumers ensuring life-saving, rescue and evacuation of workers, and also for carrying out checks, preparation and bringing into operation of the auxiliary or main power installation after accidents (the emergency power installation).
166. The power installations are located outside explosion-hazardous rooms and zones.
167. A diesel generator equipped with systems for automatic starting of the diesel engine is used as the emergency power installation. Starting of the emergency power installation is ensured without consumption of electricity from outside, within a total time for starting the diesel engine and taking up the load by the generator not exceeding 45 seconds.
168. The emergency power installation is located in a separate room precluding its damage in the event of accidents at the location of the main and auxiliary power installations.
169. Control of the power installations is carried out both from the TsPU and from the control panels located in the rooms of each installation.
170. The control posts of the power installations are equipped with mnemonic diagrams. These mnemonic diagrams are displayed on the monitor of the automated process control system in the TsPU.
171. At the entrances to automated machinery spaces, safety signs are posted bearing the inscription: "Attention! Machinery starts automatically".
172. The exhaust pipes of the power installations are led out of the rooms to the outside, taking account of the prevailing wind direction, and are equipped with silencer-spark arresters.
173. The use of devices altering the back pressure at the exhaust and the vacuum at the inlet of the engine of a power installation that have not been agreed with the engine manufacturer shall not be permitted.
174. To avoid the accumulation of fuel or oil vapours in the air ducts of the power installations, they shall be cleaned of oil deposits no less than once every 6 months with steam or an approved cleaning agent, with subsequent purging with compressed air.
175. The electrical networks on the MSP, PBU, ME and PTK are insulated, including three-phase alternating-current networks with a voltage up to 1000 V with an insulated neutral. The neutral of electrical networks with a voltage above 1000 V is earthed through a high-resistance resistor.
176. No less than once every 6 months, the cable networks are inspected, and the following are checked: the quality of the fastening of the cables; the integrity of the protective sheath of the cable; the condition of the earthing of the metal braid of the cable; the sheath of the lead-sheathed cable and the pipe in which the cable is laid; the presence of marking on the cable; the quality of the preservation of the reserve cores of the cable; the absence of contamination at the locations where the cable is laid; the condition of the anti-corrosion coating of the cable with a metal braid.
177. On the cable cabinet, a clear inscription is applied indicating the numbers of the cables and the numbers of the switchgear to which the cables are connected, and their voltages, and safety signs are also applied.
178. For connecting cables with a voltage above 1000 V, the use of cable cabinets shall not be permitted.
179. Earthing of a mobile electrical laboratory or of a separate apparatus is carried out by connecting their enclosures to the steel structures of a hazardous production facility of the MNGK by means of a bolted connection or an earthing clamp.
180. During inspection, repair work or laying of a cable after repair, the accidental application of voltage to the cable being laid, inspected or repaired is precluded.
181. After the completion of the work and receipt of written confirmation from the person in charge of the work, the responsible power-supply attendant personally satisfies himself that this work has ceased, makes an entry to this effect in the work order, after which the power supply is switched on.
182. The simultaneous performance of testing and repair work by different work teams within a single connection shall not be permitted.
183. Before the damaged cable is raised on board the cable-laying vessel, the cable is disconnected on both sides and earthed.
184. On a metal derrick, mast and other structures rising above the MSP, PBU, ME and PTK, it is permitted not to install a lightning-arrester device if reliable electrical contact of the derrick or mast with the steel structure of the MSP, PBU, ME and PTK is provided by design.
185. The connections between the air terminal, the down conductor and the earth electrode are made by welding or by bolted clamps of copper (copper alloys) or of steel with a protective coating against corrosion.
186. When receiving (transferring) fuel and bulk materials from a vessel by means of flexible special electrically conductive hoses, continuous electrical connection between the pipelines of the vessel and the MSP, PBU, ME or PTK is ensured.
187. To protect against static electricity, metal fittings, tanks, pipelines, air ducts and loading-unloading devices located inside and outside the rooms of hazardous production facilities of the MNGK are earthed. Non-conductive inserts are shunted by conductive jumpers and earthed.
188. A singly installed technical device (equipment, tank, apparatus, unit) is earthed independently or is connected to the common earthing main of a hazardous production facility of the MNGK located near the equipment by means of a separate earthing wire (bus). The series connection of several objects being earthed into an earthing bus (wire) shall not be permitted.
189. On the MSP, PBU, ME and PTK, only the use of electrical installations with an insulated neutral at a voltage up to 1000 V, and with a neutral earthed through a high-resistance resistor at a voltage above 1000 V, is permitted. In this case, insulation monitoring with automatic signalling of a reduction in the insulation resistance of the network is provided.
190. To ensure safety, the metal parts of electrical installations, the enclosures of electrical equipment and the equipment driven by these motors are earthed - are connected by earthing conductors to the earth electrode.
191. The metal parts of electrical equipment, the metal braids (sheaths) of cables, the metal structures for fastening live parts and other structures of a hazardous production facility of the MNGK that are not live but are accessible to touch under operating conditions are earthed, with the exception of: electrical equipment supplied with current of a safe voltage; the enclosures of specially insulated bearings; the bases of the lamp holders and the fastening elements of fluorescent lamps, lampshades and reflectors; the casings attached to lamp holders made of insulating material or screwed into such material; the fastening elements of the cable; single consumers with a voltage up to 250 V supplied from an isolating transformer.
192. The connection of earthing conductors to the earth electrode and to the structures being earthed is made by welding, and the connection to the enclosures of electrical equipment - by welding or bolted connections. The connection of earthing conductors is carried out in locations accessible for inspection.
193. The determination of the technical condition of the earthing device is carried out once a year, and the following is performed: an external inspection of the visible part of the earthing device; an inspection with a check of the circuit between the earth electrode and the earthed elements (the absence of breaks and unsatisfactory contacts in the conductor connecting the apparatus to the earthing device), as well as a check of the breakdown fuses of the transformers; measurement of the resistance of the earthing device; a check of the "phase-neutral" circuit; a check of the reliability of the connections of the natural earth electrodes. The results of the check are entered in the log of checks of earthing devices in written or electronic form and are documented by an act.
194. The use of steel ropes and mooring lines for earthing of the hull shall not be permitted.
195. The portable earthing is first connected to the metal structure of the MNGK hazardous production facility, and then applied to the live parts and securely fastened to them by means of clamps, grips and other fixtures.
196. It shall not be permitted to use for earthing conductors not intended for this purpose, or to connect the earthing by twisting.
197. The training and certification in the field of industrial safety of workers, including managers, are carried out in accordance with the requirements established by Article 14.1 of Federal Law No. 116-FZ of 21 July 1997 "On Industrial Safety of Hazardous Production Facilities" (Collected Legislation of the Russian Federation, 1997, No. 30, Art. 3588; 2018, No. 31, Art. 4860).
198. Workers engaged in work on the diagnostics of the condition of structures, equipment and other technical means shall undergo a knowledge assessment and obtain the right to carry out such work.
199. Workers shall be proficient in the techniques of providing first aid to persons injured in accidents.
200. The management and performance of work on drilling, development, repair, reconstruction, conservation and abandonment of wells, the conduct of geophysical work in wells, and also on the extraction, gathering and treatment of oil and gas, may be undertaken by persons who have professional education corresponding to the position held and who are certified in the field of industrial safety.
201. Workers directly managing and performing work on drilling, development, repair, reconstruction, conservation and abandonment of wells, and the conduct of geophysical work and PVR on wells, shall, once every 2 years, additionally undergo a knowledge assessment on well control and well management during GNVP. This requirement does not apply to workers performing designer's supervision and scientific support for the introduction of technological processes, technical devices and tools.
202. Workers of integrated crews, where it is necessary to perform work requiring the combination of occupations, shall undergo training and obtain the appropriate qualification for the types of work performed, and shall hold clearances for independent work in the combined occupations.
203. Workers who have arrived at the hazardous production facility for work shall be familiarised with the hazardous and harmful production factors, the signs of their manifestation, the actions for specific types of alarms, and other matters falling within the scope of the induction briefing.
204. Information on the conduct of the briefing is recorded in special logs with the confirming signatures of the person being briefed and the person conducting the briefing.
205. The recruitment for work at the MNGK hazardous production facility of persons under 18 years of age shall not be permitted.
206. The operation of lifting devices may be undertaken by persons who meet the qualification requirements, as well as the requirements established in the manuals (instructions) of the manufacturer for the operation of these devices, and who have an electrical safety group of not less than II.
207. Workers engaged in the slinging and rigging of loads moved by lifting devices with the use of load-handling attachments shall have a level of qualification corresponding to the occupation of "slinger".
208. The following documents, which are mandatory for study by workers within the scope of their job duties, shall be kept at the MNGK hazardous production facility: process regulations; instructions or plans for the safe conduct of work or operations; manuals or instructions for the safe operation of equipment or of the MNGK hazardous production facility as a whole; internal regulations; the alarm schedule; the PMLA; the instruction on the prevention of GNVP and open blowouts (when performing drilling work, well repair and well operation).
209. Among the personnel of the MSP, PBU, ME and PTK, an emergency crew trained to work in breathing apparatus is formed.
210. The wells specified in paragraph 2 of these Rules shall be sited outside the boundaries of the sanitary protection zone of water supply sources and drinking water pipelines, the protection zones of LEP, trunk oil and gas pipelines, water intake and other industrial and civil facilities.
211. The main document for the performance of drilling work is the working design developed by the subsoil user and approved in accordance with the requirements of Section XIV of these Rules and other regulatory legal acts governing the design procedure.
212. The commissioning of the drilling rig, auxiliary structures and technical devices at the drilling site is carried out after the completion and quality inspection of the rig-up work, the testing of the technical devices, where a fully staffed drilling crew is available and where the positive results of the tests and checks specified in paragraph 313 of these Rules are obtained.
213. A copy of the act on the commissioning of the drilling rig is sent to the territorial body of Rostechnadzor for information within a period not exceeding 3 working days from the moment of commissioning of the drilling rig.
214. When special work is performed by the drilling crew (for example, moving the drilling rig, installation of mobile drilling rigs, repair work of increased complexity), the crew workers shall undergo additional training and obtain clearances for independent work in the main and combined occupations.
215. At all stages of the performance of drilling work (including work performed by contractors and subcontractors), the availability and functioning of the necessary instruments and systems for monitoring the production process shall be ensured in accordance with the requirements of the working design.
216. Monitoring of the progress of drilling work, of the quality of performance of this work, of technological processes and operations, of the quality of the materials and technical means used, and of compliance with safe working conditions shall be carried out by the subsoil user (the customer), the organisation performing the drilling work, and other economic entities authorised by the subsoil user.
217. The performance of drilling work under specific conditions (in MMP; at fields with a hydrogen sulphide content in the oil (gas) of more than 6 per cent (by volume); from cluster pads; MNGK hazardous production facilities; for the extraction of methane from coal seams) shall be carried out with the application of additional safety measures established by Sections XXVII, XLVII, XXVIII and XXIX of these Rules.
218. The drilling of oil, gas and gas-condensate wells is carried out in accordance with the documentation for the performance of drilling work (the working design), one copy of which (or its electronic version) shall be at the place of performance of the work.
219. Overall management of drilling work is assigned to the head of the MNGK hazardous production facility, and for the period of his absence - to the person acting in his place.
220. Vessels may be moored to the PBU only under favourable weather conditions, in a specially designated place, and with the permission of the master of the PBU. The mooring of vessels and the receipt and transfer of cargo during the setting of the PBU on the drilling point shall not be permitted.
221. Before the onset of the period of ice formation and drift of ice fields hazardous to the operation of the PBU, the operating organisation withdraws the PBU from the hazardous area in good time.
222. When the sea state and wind intensify, when the movements of the PBU above the drilling point exceed the permissible limits established in the operational documentation, and also in the event of the appearance of drifting ice fields, drilling is stopped and the drilling riser is disconnected from the wellhead so that the PBU can move away to a safe distance. In doing so, actions are carried out to ensure the re-entry of the drilling tool into the well when the PBU returns to the point of performance of work. Well drilling work is resumed only after checking the tightness of the lower connecting unit of the riser with the PPVO block and of the connections of the discharge lines (killing and choke).
223. For the entire well drilling cycle, a tool for suspending the drill string in the subsea wellhead or PVO, assembled and set on the fingerboard, shall be available in case of disconnection of the connecting unit of the riser from the PPVO block.
224. For the entire period of use of the PPVO (after installation and until dismantling), the operability of not less than two hydraulic control lines of the PPVO shall be ensured.
225. The procedure for the emergency removal of the PBU from the drilling point (emergency disconnection from the wellhead) under unfavourable hydrometeorological conditions, in the event of the formation of a griffon under the PBU and the arising of the associated hazard, and under other conditions posing a threat to the safety of the PBU, shall be defined in the PMLA.
226. On the PBU, continuous accounting of the weight and placement of materials, fuel, water and other cargo is maintained.
227. On a PBU with a dynamic positioning system and (or) an anchor holding system, the following are continuously recorded and monitored: wind speed and direction; the parameters of roll, pitch and heave; yaw (rotations about the vertical axis); horizontal displacement; the draught of the vessel; the inclination angle of the drilling riser; wave height; current speed.
228. During drilling and the performance of other technological operations, the operator of the PBU positioning system continuously monitors the position of the PBU above the well, the horizontal movements of the PBU and the inclination angle of the drilling riser.
229. Drilling work may be performed under hydrometeorological conditions corresponding to the operating manual of the PBU.
230. Permission for the performance of individual technological operations and the application of restrictions on the operation of the drilling equipment, as well as instructions on stopping drilling and disconnecting the drilling riser owing to hydrometeorological conditions, are issued by the head of the PBU.
231. In the case of direct signs of GNVP, the wellhead shall be sealed in accordance with the PMLA and measures shall be taken to kill the well: - the head of the PBU reports the occurrence to the management of the operating organisation; - observation for the possible formation of griffons is organised on the PBU; - in the event of the appearance of griffons in the area where the PBU is located and the creation of a threat to the PBU, the head of the PBU, together with the master, urgently takes measures to move the PBU away from the point of performance of work. All work on sealing and disconnection from the wellhead is directed by the head of the PBU.
232. All work on sealing and disconnection from the wellhead is directed by the head of the PBU.
233. Where it is necessary to move away from the subsea wellhead, when formations with abnormally high formation pressure or productive horizons have been penetrated by the well, the sealing of the wellhead is carried out while the drilling tool is at the shoe of the last casing string.
234. Before the start of drilling of the pilot hole of the well (to determine the possible presence of gas in the upper intervals of the geological section) on the MSP, PBU and ME from which drilling is performed, a kill fluid is prepared for the elimination of a possible gas show of shallow (near-surface) gas, and actions to ensure safety and rapid response are prepared to prevent loss of control over the well. Control over the wellhead is carried out by means of a television camera.
235. During the drilling of the pilot hole, observation of the surface of the water area around the MSP, PBU and ME is ensured.
236. The drilling rig is equipped with a top drive system (top power drive).
237. The drilling complex is equipped with not less than two standpipes of the drilling pump manifolds.
238. Pipes from the racks are fed onto the catwalk by means of cranes or automated systems installed at the MNGK hazardous production facility. The rolling of pipes from the racks onto the catwalk shall not be permitted.
239. In the event of unfavourable hydrometeorological conditions, the head of the drilling complex takes a decision to stop or suspend the tripping operations.
240. The drilled cuttings and spent flushing fluids are disposed of.
241. When powdered materials (clay powder, cement, chemical reagents) are used, sealed equipment with a device for pneumatic conveying is installed.
242. Cementing of the casing string in the well is carried out by cementing equipment located on the MSP, PBU, ME and PTK or on a specialised vessel.
243. The places of installation of shut-off valves on the pipelines of the pneumatic conveying system located at height are equipped with service platforms with railing guards and gangways (ladders).
244. Storage tanks and discharge tanks (dischargers) are equipped with quick-opening manholes.
245. The cover of the manhole is fitted with a seal and a device for fixing it in the open position.
246. All pipelines are marked according to the type of the conveyed agent, with indication of the direction of its movement.
247. On the pipelines of the pneumatic conveying system, at the places of possible deposits of powdered material and formation of plugs, purge valves with a supply of compressed air are installed.
248. The discharge of spent air from the cyclones is carried out from one of the opposite sides of the MNGK hazardous production facility depending on the direction of the wind.
249. The formation of the subsea wellhead is carried out in accordance with the plan for the safe conduct of work approved by the operating organisation. The plan takes into account the condition of the sea bed, the type and method of running and installation of the base plate (if any), the guide base, the casing string being run, and the recommendations of the manufacturers of the specified equipment.
250. Before the start of work on the formation of the wellhead, the person in charge of the drilling work conducts a briefing of workers on the main technological features of the work connected with the formation of the subsea wellhead, and also on the safe operation of the drilling rig. The briefing conducted is registered in the log of briefings.
251. The commissioning of the drilling rig, auxiliary structures and technical devices is carried out after the testing of the technical devices, where a fully staffed drilling crew is available and where the positive results of the tests and checks are obtained.
252. Before the start of drilling of the well, the technical manager of the operating organisation approves the act of readiness of the drilling rig. A copy of the act on the commissioning of the drilling rig is sent to the territorial body of Rostechnadzor for information.
253. The order of the responsible person on the start of work on the formation of the subsea wellhead is recorded in the ship's log and the drilling log.
254. Work on the formation of the wellhead without stabilisation (orientation) of the PBU at the drilling point shall not be permitted.
255. The installation of the base plate (if any) on the leaves of the spider platform is carried out so that the centre of the plate coincides with the axis of the tool being run (the centre of the rotary table).
256. The presence of people on the leaves of the spider platform during their movement shall not be permitted.
257. Work on the preventer (spider) platform and in other places associated with the risk of falling into the sea shall be performed wearing life jackets and safety belts securely fastened to the structure of the MNGK hazardous production facility.
258. The base plate (if any) is installed on a level surface of the sea bed with a slope of not more than one degree.
259. The landing of the base plate (if any) on the ground is carried out with the use of a motion compensator to ensure smooth landing of the plate and to prevent impact.
260. Before the start of rotation of the drum of the PPVO control umbilical during the running or hoisting of the PPVO block, the connecting box of the umbilical linking the drum with the hydraulic power unit shall be disconnected from the drum.
261. The running of the PPVO and the drilling riser shall be carried out when the vertical movement of the PBU does not exceed the value corresponding to the technical characteristics of this type of unit.
262. When a compensator of vertical movements of the drill string is used for running the riser sections with the PPVO and for docking the PPVO with the subsea wellhead, the compensator is preliminarily adjusted to maintain the weight of the drilling riser at the value established by the documentation for the construction of the well.
263. When running the riser sections with the PPVO, every 8 - 10 m the umbilicals of the control system are fastened by means of clamps to the killing and choke lines on the riser sections or to the ropes of the collector.
264. When running the riser sections with the PPVO, pressure testing of the killing and choke lines is carried out to a pressure not less than the maximum expected at the wellhead.
265. The docking of the PPVO with the subsea wellhead is carried out with the compensator of vertical movements of the drill string switched on, and the process is monitored by means of a remotely operated underwater vehicle.
266. After running the drilling riser with the PPVO and installing the diverter, the seal of the diverter body, the diverter packer, the valve of the flow line, and the valves of emergency discharge and filling are checked for tightness, and after connecting the diverter body to the mud line, its tightness is checked.
267. The check of the reliability of the docking of the PPVO with the wellhead is carried out in accordance with the installation and operating instruction of the manufacturer of the PPVO, with subsequent hydraulic pressure testing to a pressure not less than that expected at the wellhead.
268. Visual monitoring of the connections of the drilling riser and the PPVO block underwater is carried out by means of a remotely operated underwater vehicle.
269. The testing and development of wells on the MSP, PBU, ME and PTK are carried out on the basis of the plan for the safe conduct of work developed and approved by the operating organisation.
270. During the well testing period, an ASS shall be constantly present near the MSP, PBU, ME and PTK.
271. Before the testing and development of wells, the following shall be done: check the completeness and readiness of the fire-fighting means and rescue means; check the fastening units and the boom of the flare and the pipeline systems of the device for burning the well production; check the ignition systems of the burners and the serviceability of the remote device for igniting the flare; pressure-test the separator together with its piping, and also the pipeline system of the device for burning the well production; light the pilot burner of the flare.
272. The well testing production passes through the separator and is then fed to the flare located on the leeward side of the MSP, PBU, BS and ME.
273. The capacity of the burners for the well production burning unit is determined in accordance with the expected quantity of production of the well being tested.
274. When burning the well testing production, the supply of water and air to the flare shall be regulated to ensure smokeless burning of the well production.
275. Work on the testing (development) of a well with a subsea wellhead begins only after a functional check of the operability of the PPVO, pressure testing of the PPVO with the production casing, a check of the operability of the valve block of the subsea Christmas tree (the test and production trees), and a check of the tightness of the tubing string and the deck test equipment.
276. For wells with a subsea wellhead, a check of the operability of the valve block of the subsea Christmas tree (the test and production trees) is required for the burning of the well production.
277. The servicing of the wellheads of offshore wells on the MSP and PTK is carried out by not less than two workers.
278. A flowing well is equipped with a downhole safety valve and a Christmas tree with remotely controlled cut-off gate valves.
279. The control station for the downhole safety valves and the remote control device for the gate valves of the Christmas tree are installed in a separate room outside the explosion-hazardous zone.
280. The operability of the downhole safety valves and the cut-off gate valves is checked according to a schedule approved by the operating organisation, in accordance with the instruction of the manufacturer.
281. In flowing wells, monitoring of the pressure in the tubing and annular spaces is carried out.
282. The operation of wells with pressure in the intercasing space caused by the leakage of casing strings shall not be permitted.
283. Pipelines from the wellheads to the process units are laid in a single tier and are designed for one and a half times the working pressure. At the beginning and at the end of the pipeline, the well number and the direction of flow are applied with paint.
284. The purging and bleeding-off of wells, pipelines, separators and other process equipment are carried out through the purge and bleed-off unit.
285. An individual or group working design for the performance of drilling work (hereinafter - the working design) is developed: for the drilling of a single well; for the drilling of a group of wells located on one cluster pad or one field or area. The development of a working design for the drilling of a group of wells is carried out where the following factors are common: the purpose of the wells; the design depths along the well bore; the design of the wells - identical diameters of the casing strings and their number (without taking into account the conductors). The deviation of the running depths of the casing strings specified in the working design shall not exceed 400 m along the vertical; the density of the drilling fluid, differing from that provided for in the working design within +/- 0.3 g/cm3 (except in cases of elimination of GNVP and complications); the mining and geological conditions of drilling; the conditions of nature management.
286. The inclusion of wells having a deviation, under the working design for the drilling of a group of wells, in vertical depth of 400 m between the deepest and the shallowest well is permitted, provided that the difference in bore length between the longest and the shortest well shall not exceed 4000 m.
287. The performance of drilling work at each subsequent well under the working design for the drilling of a group of wells shall be carried out taking into account the experience of drilling the previous wells.
288. The repeated use of the working design for the performance of drilling work at subsequent wells and at wells on areas and fields identical in geological and technical conditions is permitted. The repeated use of the working design may be carried out where the factors specified in paragraph 285 of these Rules are common.
289. The repeated use of the working design is documented by a protocol of the commission established by the subsoil user (the customer) and is agreed with the design organisation. The protocol specifies the area (the field section) and the numbers of the new wells.
290. The working design being developed shall take into account the experience of the performance of drilling work at wells in the given and the nearest areas with similar conditions, and shall ensure the reliability and safety of the subsequent operation of the well.
291. The working design shall contain the following data and decisions: the geographical and climatic characteristics of the work area; the mining and geological conditions of drilling; the justification of the well design; the profile of directional and horizontal wells; the combined graph of formation (pore) pressures and fracturing pressures; the expected wellhead pressures during GNVP; the initial data for the calculation of the casing strings with the accepted safety factors used in the calculations; the final tables of the layouts of the casing and tubing strings and the types of threaded connections of the casing and NKT; the regulations for running the casing strings (for example, running speeds, make-up torques); the justification of the density of the drilling fluid and the range of variation of other parameters of the flushing fluid; the drilling method, the layout of the drill pipe string with indication of the strength group, wall thickness, safety factor and type of tool-joint connections, the speed of tripping operations; the type of cementing material, the properties of its set cement and slurry (spreadability, water loss, the onset of thickening and setting, permeability, strength, resistance to aggressive media), the method and the hydraulic programme of cementing based on the mining and geological conditions; the control of the cementing process and the study of the condition of the casing support after the hardening of the cement slurry; the scope of the investigation of the stratigraphic section during drilling to refine the formation pressures and the fluid composition; the technology of secondary opening of formations (perforation) and the types of technical devices used for this; the methods of well development, testing, testing of formations in the well, the methods of inflow stimulation and the programme of geological and geophysical surveys; the tie-in diagrams of the wellhead, the PVO and the Christmas tree, the technical characteristics of the gland seals and the wellhead pressure during pressure testing together with the casing strings, the procedure and conditions for pressure testing of the intercasing spaces; the arrangement of the cellar (if necessary); the geological and technical order for the performance of drilling work; the type and dimensions of the foundations for the drilling rig, which are determined on the basis of the load on the base, the permissible specific load on the ground and the safety factor for the given ground; the means of protection of workers and the composition of the KIP, including for monitoring the condition of the air environment when opening productive horizons with aggressive fluids; the volume of the reserve of drilling fluid; the actions for the prevention and early detection of GNVP; the methods of assessing the condition of the casing strings, the methods and frequency of their testing for residual strength.
292. The design and layout of the casing head assembly and the Christmas tree shall ensure the optimal operating modes of the well, the possibility of sealing the tubing, annular and inter-tubing spaces, the possibility of performing technological operations in the well, deep investigations, sampling, and monitoring of the wellhead pressure and temperature.
293. When complications arise during the performance of drilling work (GNVP, losses, cave-ins and others), operational decisions on deviation from the parameters provided for in the working design are taken by the drilling contractor with subsequent notification of the customer.
294. During the performance of drilling work, the organisation that developed the working design exercises designer's supervision, including when implementing nature-protection actions.
295. The well design, as regards reliability, manufacturability and safety, shall ensure: the maximum use of the formation energy of the productive horizons during operation through the choice of the optimal diameter of the production casing and the possibility of achieving the design level of hydrodynamic connection of the productive deposits with the well bore; the use of effective equipment, optimal methods and modes of operation, maintenance of formation pressure, thermal treatment and other methods of increasing the oil and gas recovery of the formations; conditions for the safe conduct of work without accidents and complications at all stages of the performance of drilling work and operation of the well; the obtaining of the necessary mining and geological information on the section being opened; conditions for the safe conduct of work connected with the use of subsoil and the protection of the environment, primarily through the strength and durability of the well casing support, the tightness of the casing strings and the annular spaces, and also the isolation of fluid-bearing horizons from each other, from permeable rocks and from the space around the wellhead.
296. The optimal number of casing strings and the depths of installation of their shoes, when designing the well construction, are determined by the number of zones with incompatible conditions of bore drilling according to the gradients of formation (pore) pressures, fracturing (loss) of formations, and the strength and stability of the rocks.
297. The shoe of the casing string overlapping rocks prone to creep shall be installed below their base or in dense interlayers.
298. Before opening the productive and pressurised water-bearing horizons, the running of at least one intermediate casing or conductor to a depth precluding the possibility of rock rupture after the complete replacement of the drilling fluid in the well by formation fluid or a mixture of fluids of different horizons and after sealing of the wellhead shall be provided for.
299. The necessary difference in the diameters of the wells and the couplings of the casing strings, as well as the diameters of the casing pipes when running couplingless casing strings, is established in the working design and is selected on the basis of the optimal values established by the practice of the performance of drilling work and ensuring to the maximum the unimpeded running of each string to the design depth, as well as their quality cementing.
300. The suspension and sealing device of the liner string shall be installed above the shoe of the previous casing string by not less than 75 m for oil wells and 250 m for gas wells. The suspension and sealing device of a non-cemented tail pipe installed in the productive formation shall be located above the shoe of the previous casing string.
301. The selection of casing pipes and the strength calculation of the casing strings are carried out taking into account: the maximum expected excess external and internal pressures upon complete replacement of the drilling fluid (kill fluid) by formation fluid or a gas-liquid mixture; the reduction of the hydrostatic level during development or during mechanised production; the loads arising as a result of the spatial deviation of the well bore; the axial loads on the pipes and the aggressiveness of the fluid at the stages of the performance of drilling work and operation of the well. The strength of the conductors and the technical casings, as well as of the wellhead equipment, shall be confirmed by a calculation of the maximum volume of fluid that has entered the well (Vpred), at which killing of the show is possible without exceeding the permissible pressures for each uncased formation opened by the well. The strength of the conductors, the technical casings and the PVO installed on them shall ensure: sealing of the wellhead in cases of GNVP, blowouts and open blowout, taking into account an excess of the additional pressure required to kill the well by not less than 10 per cent; stability (preservation of integrity) under the action of the hydrostatic pressure of a column of drilling fluid of maximum density; withstanding the action of the maximum compressive loads in cases of open blowout or loss with a drop in the level of the drilling fluid, and also in the intervals of occurrence of rocks prone to creep.
302. The design of the wellhead and of the sealing devices shall ensure: suspension, with the design tension, of the intermediate and production strings, taking into account compensation of thermal deformations at all stages of operation of the well (string), and also suspension of the drill pipe string on the BOP equipment; monitoring of possible fluid shows behind the casing strings; the possibility of emergency killing of the well; leak-tightness of the intercasing spaces during drilling and operation of the well; testing of the casing strings and of the intercasing spaces for leak-tightness.
303. The operation of wells drilled before the entry into force of these Rules without casing heads is permitted, provided that the leak-tightness of the space between the casing strings is ensured.
304. The frequency and methods of checking the condition of the casing strings and casing heads, as they undergo natural wear or emergency failure (collapse, rupture and other deformations), and the necessary actions to ensure the safety of drilling operations and of well operation are established by the working design or by other documentation containing similar requirements.
305. The design of the well shall provide for the possibility of a workover of the well, including by kicking off and drilling a new wellbore.
306. The size of the land plot for carrying out drilling operations shall have an area ensuring compliance with the industrial safety requirements established by the well construction design.
307. When carrying out drilling operations on agricultural land, the established requirements for the turnover of agricultural land shall be followed.
308. The sites for installation of the drilling rig shall be laid out taking into account the natural slope of the terrain and ensuring the flow of wastewater into the system for its collection and treatment. The BOP equipment manifolds shall be positioned with a slope away from the wellhead.
309. The technical documentation for the transportation of a large block with the derrick, of the derrick separately in the vertical position, and of the blocks of mobile drilling rigs is approved by the management of the organisation carrying out the derrick erection work, after coordination of the route with all interested organisations. The work is performed under the supervision of a responsible employee who has clearance to supervise such work.
310. The technical documentation shall reflect: the method of transportation of the equipment; the route of movement of the equipment and the paths of movement of the supporting and safety machinery; the methods of overcoming ditches and ravines, of levelling the route, including across forest clearings, and of crossing roads, power lines and water obstacles; the number and arrangement of the members of the work team involved in the transportation of the equipment, and the participation of representatives of the organisations operating the power lines and railways (in the event of their crossing).
311. The dismantling of an electrically driven drilling rig may be commenced after receipt of written confirmation from the employee responsible for the operation of the electrical equipment that the drilling rig has been disconnected from the power mains. The dismantling of the drilling derrick and of the derrick-and-drawworks unit while there is pressure at the wellhead shall be prohibited.
312. The anchors of the wind guy lines (if any) of the derrick (mast) shall be tested for the loads established by the operating manual of the manufacturing plant.
313. After installation of the drilling rig, leak-tightness tests of the discharge pipelines, air lines, equipment control systems and interlocks, and a check of the quality of the earthing of the equipment and of the earthing devices, are performed.
314. The technical characteristics and the completeness of the set of the equipment of the drilling rig, and of the auxiliary equipment required for carrying out drilling operations, are established by the working design.
315. The minimum required lifting capacity of the drilling rig shall be determined in the working design on the condition that the sum of the static and dynamic loads when running in (pulling out) the heaviest drill strings or casing strings, and also during the elimination of accidents (sticking), does not exceed the value of the "permissible hook load" parameter of the selected drilling rig. The hook load from the maximum design mass of the drill string and the greatest design mass of the casing strings shall not exceed 0.6 and 0.9 of the "permissible hook load" respectively. The selection shall be made according to the greater of these loads. Where process operations are carried out in the cased hole, the hook load from the maximum design mass of the drill string shall not exceed 0.9 of the "permissible hook load".
316. Drilling rigs shall be equipped with a top drive when: drilling wells from a depth along the hole of more than 4500 metres; penetrating formations with an expected content of hydrogen sulphide in the formation fluid in excess of 6 per cent (by volume); building up the angle with a radius of curvature of less than 30 metres in directional and horizontal wells; drilling a horizontal section of the wellbore more than 300 metres long in wells with a vertical depth of more than 3000 metres; drilling all offshore wells.
317. Control of the drawworks shall be carried out from the driller's console. Starting of the drilling pumps shall be performed from the local control station, and the regulation of their operation and their stopping - from the driller's console and the local control station.
318. The control of the lifting mechanisms for work on the catwalk shall be remote. Work involving the movement of loads weighing more than 30 kg shall be mechanised.
319. The design of the auxiliary winch shall ensure smooth movement and reliable holding of the load in suspension. From the winch control console, the operator shall be provided with a view of the work site and of the movement of the load. It is permitted to install a duplicate control console.
320. The drilling rig shall be equipped with: a limiter of the lifting height of the travelling block; a permissible-hook-load limiter; interlocking devices for switching off the drive of the drilling pumps when the pressure in the discharge pipeline exceeds by 10 per cent the maximum working pressure of the pumps for the corresponding cylinder liner; a station (instruments) for monitoring the drilling parameters (the type of station is determined by the customer); a catwalk with a horizontal section not less than 14 metres long and not less than 2 metres wide, and pipe racks. When stacking pipes, special spacers and side stops shall be used. The height of the pipe stack shall be not more than 2 metres, but not higher than the width of the pipe rack. The pipe racks shall have not less than two passages to the catwalk on each side. Where the height of the pipe rack is below the catwalk, the delivery of pipes to the catwalk shall be mechanised; an increase in the height of the pipe stack up to 3 metres is permitted where the stability of the pipe rack and of the pipes stacked on it is ensured in accordance with the technical solutions provided for by the design and engineering documentation of the drilling rig; equipment for the preparation, treatment, weighting, cleaning, degassing and mixing of the mud, and for the collection of cuttings and spent fluid in pitless drilling; a device for drying the air supplied to the control pneumatic system of the drilling rig; a damper for the running end of the drilling line; workplace heating systems; interlocking devices to prevent engagement of the rotary table when the guards are removed and the rotary slips are raised; a device (belt) for A-frame masts and derricks with an open front face, preventing the falling of stands being set (set) behind the finger; a system of reserve and suction tanks fitted with level gauges and automatic alarms for monitoring the level of liquid in them; a graduated measuring tank for the controlled filling of the well, fitted with a level gauge for monitoring the filling of the well.
321. All enclosed rooms of the drilling rig where the occurrence or ingress of flammable mixtures is possible are equipped with mechanical supply-and-exhaust ventilation ensuring air exchange in accordance with the requirements of the sanitary norms and rules. The operating mode of the ventilation from the moment of penetration of the productive horizon until completion of drilling of the well shall be continuous. When 20 per cent of the lower flammability limit of the mixture of air and hydrocarbons is reached, a warning signal shall be activated, and when 50 per cent of the limit is reached, a complete shutdown of the equipment and mechanisms shall be ensured.
322. When carrying out drilling operations, the base of the drilling derrick shall provide for the possibility of installation of: the BOP equipment at the wellhead and dismantling of the base with the wellhead assembly or a part thereof installed; the rotary table at the level of the rig floor, and also of rational arrangement; the means of automation and mechanisation and the control consoles; a heated setback with mud drainage; air, oil and fuel lines and the means of the heating system; the mechanism for fastening the fixed strand of the travelling system; the mechanisms for changing the height position of the tongs; the mechanism for fastening the working and safety ropes of the tongs; ratholes for making up connections, for setting the kelly and (if necessary) the drill collars; devices for mechanising the setting of the kelly and the drill collars into the ratholes.
323. When carrying out drilling operations on a well cluster, the movement of the substructure of the derrick shall be ensured by special technical devices that take up the inertial load during movement, depending on the mass of the drill pipe stands located behind the fingers. During operation of the drilling derrick, the possibility of accumulation of water in its elements shall be excluded.
324. The fastenings used for all fixtures and devices installed on the derricks shall preclude their spontaneous loosening and falling. The fixtures and devices shall be secured against falling.
325. Where the stands are arranged manually, the derricks are equipped with a derrickman's platform with a device for his evacuation in the event of an emergency situation. The device shall be located outside the derrick and shall ensure evacuation of the derrickman beyond the interior space of the derrick.
326. The drilling derrick and its fastening to the base shall be designed (at a stability factor of 1.4) for the overturning moment at a wind speed of 33.5 m/s and with a full set of drill pipe stands behind the fingers, without taking into account the influence of the guy lines. The fastening of the derrick to the base or foundation, taking into account the guy lines, shall prevent its overturning.
327. The working platform of the base under the drilling derrick shall have an enclosure along the entire perimeter, not less than 6 metres high, made of a non-readily-flammable material. The enclosure on the side of the catwalk shall have a gate opening outwards; the dimensions of the gate shall be equal to the width of the catwalk and the height of the enclosure respectively. In the enclosure of the working platform and at the necessary places, exits shall be provided, fitted with doors opening outwards and protected against accidental slamming and detachment from the fastening point, with a height of not less than 2 metres and a width of not less than 0.75 metres.
328. Pressure compensators, filled with air or inert gas, shall be installed on the drilling pumps. The design of the pressure compensator shall provide for the installation of a pressure gauge for measuring the pressure in the gas cavity and shall provide the possibility of releasing the pressure to zero.
329. The drilling pumps are securely fastened to the foundations or to the base of the pump block, and the discharge pipeline - to the block bases and the intermediate stands. The bends of the pipelines are made smooth or are made rectangular with baffle elements to prevent erosion wear. The design of the fastening of the elements of the discharge pipeline to the metal structures shall provide for the possibility of centring the travelling system relative to the axis of the well. Removable metal clamps are installed on the flange connection of the discharge pipeline.
330. The antiblowout fittings system of the bore section of the top drive shall include not less than two built-in ball valves. One of the valves shall be equipped with remote control from a console. The working pressure of the ball valves shall be not less than the maximum permissible pressure of the other elements of the discharge pipeline of the drilling rig, and their bore cross-section shall correspond to the bore cross-section of the bore section of the drive. During operation, the following shall be monitored: the rotation speed of the drill string; the magnitude of the torque during make-up and drilling; the position of the elements of the pipe handler; the position of the antiblowout fittings system.
331. The control system of the automatic tong shall provide for the possibility of complete disconnection of the mechanisms from the working-agent supply line, and also an interlock to prevent accidental engagement.
332. On the housings of the equipment forming part of the travelling system (crown block, travelling block, hook), their permissible lifting capacity shall be indicated.
333. Mechanical transmissions, clutches, pulleys, other rotating and moving elements of the equipment, and also their protruding parts, shall have guards.
334. The procedure for organising and carrying out the scheduled repair and maintenance of the drilling and power equipment is established by the drilling organisation, taking into account the operating manuals provided by the product manufacturer.
335. The pneumatic system of the drilling rig (pipelines, cocks, connections) shall be tested at the manufacturing plants at a pressure exceeding the working pressure by 1.5 times. After installation at the work site, and also after repair work, the pneumatic system shall be tested at a pressure exceeding the working pressure by 1.25 times, but by not less than 0.3 MPa.
336. For lifting parts weighing more than 300 N (30 kgf), lifting mechanisms (for example, hoists) shall be used.
337. When carrying out repair work, fixtures and technical devices ensuring the safety of workers shall be used.
338. The safety devices of the pump shall be activated at a pressure exceeding by 10 per cent the maximum working pressure of the pump corresponding to the diameter of the installed cylinder liners.
339. If horizons with a possible gas, oil and water influx are penetrated while two pumps are operating, the possibility of their simultaneous operation from a single tank shall be provided. In the manifolding between the tanks of the circulation system there shall be shut-off devices.
340. On the discharge pipeline of the pumps, a remotely controlled valve is installed, allowing the drilling pumps to be started without load with their gradual bringing to the working mode (under pressure control). The flow line from the starting valve shall be straight and securely fastened, with a slope towards the drain.
341. On drilling rigs with an adjustable pump drive, the installation of starting valves is not mandatory, but a valve for releasing the pressure in the discharge pipeline shall be installed.
342. The discharge pipelines, their parts and fittings, after assembly, and also after repair involving welding, shall be subject to pressure testing at test pressure; in the other cases the test pressure shall be equal to the working pressure multiplied by the safety factor. The duration of holding under pressure shall be not less than 5 minutes. The working pressure and the required minimum safety factor are given below: less than 20 MPa - 1.5; from 20 to 56 MPa - 1.4; from 56 to 65 MPa - 1.3; from 65 MPa and above - 1.25. Testing of the manifold with the drilling pumps shall not be permitted.
343. The drilling hose is secured against falling by a steel rope with a diameter of not less than 12.5 mm along its entire length, fastened to the hose every 1.0 - 1.5 metres. The ends of the rope shall be fastened to the mating flanges of the swivel and the manifold. To avoid rupture of the hose when working with it, a safety valve set at a pressure 25 per cent below that permissible for the hose shall be installed on the pump unit. The bolted connections shall preclude the possibility of spontaneous unscrewing (lock nuts shall be installed, or castellated nuts shall be installed and secured with cotter pins).
344. The running and fixed ends of the drilling line under load shall not touch the elements of the derrick.
345. The tongs are suspended horizontally on steel ropes with a diameter of not less than 12.5 mm and are equipped with counterweights for ease of adjustment of the height. The balancing mechanisms of the tongs shall be guarded and shall have travel limiters.
346. The tong, in addition to the working rope, is equipped with a safety rope with a diameter of not less than 18 mm, which is fastened at one end to the body of the tong and at the other - to the base of the derrick block or to a leg of the derrick. The safety rope shall be longer than the working rope by 50 - 100 mm.
347. The reeving of the travelling system shall comply with the requirements of the working design for the given interval of wellbore drilling and with the technical operating conditions of the drilling rig.
348. Each derrick shall be provided with a metal plate attached in a visible place. On this plate the following shall be indicated: the date of manufacture of the derrick; the manufacturing plant; the factory number of the derrick (drilling rig); the permissible hook load; the dates of the next testing (checking of the technical condition) of the derrick.
349. The metal floor of the derrickman's cage shall be designed for a load of not less than 130 kgf and shall have a railing with a solid sheathing down to the floor. The height of the railing shall be not less than 1 metre. The cage shall be secured against falling.
350. Where tripping operations are carried out mechanically without the participation of a derrickman, a platform for servicing the mechanisms of the automatic tripping unit shall be installed on the derrick.
351. During tripping operations with the participation of a derrickman, his working platform shall be equipped with fingers with articulated heads for setting drill pipe stands, secured with a rope against falling in the event of their breakage, and with a height-adjustable cage to ensure safe work with stands having a deviation from the average length.
352. The condition of the load-capacity limiter of the drawworks and of the lift limiter of the travelling block shall be checked for activation before the start of work of each tour (shift).
353. Operation of the drilling rig with the protective guards not installed or damaged shall be prohibited.
354. The strength calculation of the drill string is carried out, depending on the drilling method and the condition of the wellbore, for all types of deformation. The safety margins of the drill string under the action of a static axial tensile load, torque, and also a bending load, shall be, for rotary drilling, not less than 1.5, and for drilling with hydraulic downhole motors - 1.4. The safety margin of the drill string (with respect to the yield point), when using the slips and under the action of excess external and internal pressure on the pipe, shall be not less than 1.15.
355. During drilling operations, recording of the operating time of the drill pipes, kellys, drill collars, subs, and support-and-centralising and other elements of the drill string shall be organised. Upon reaching the standard operating-time limits, the drill pipes, kellys, drill collars, subs, support-and-centralising and other elements of the drill string shall be subjected to inspection and flaw detection. The standard operating-time limits and the types of inspections and flaw detection are established at the operating organisation in accordance with the technical documentation of the manufacturing plant.
356. The need for installation of protectors on drill pipes and kellys is determined by the working design.
357. The make-up of the tool joint threads of drill pipes, kellys, drill collars, subs and other elements of the bottomhole assembly is carried out in accordance with the torque values recommended by the manufacturing plants.
358. Drilling organisations shall have, within the region of operation, special means for the "left-hand" back-off of drill pipes in the well during emergency work.
359. During drilling of the wellbore, the following parameters shall be continuously monitored: the hook load, with recording on a chart or recording by electronic information storage means; the density and the structural-mechanical and rheological properties of the drilling mud, with recording in a log or recording by electronic information storage means; the flow rate of the drilling mud at the inlet and outlet of the well; the temperature of the drilling mud at the outlet of the well; the pressure in the manifold of the drilling pumps; the pressure at the drilling choke (when drilling with back-pressure control); the mud level in the suction tanks and the filling tank during deepening, during flushing of the well and during tripping operations; the torque of rotation of the drill pipe string. The readings of the hook load, the pressure in the manifold of the drilling pumps, the magnitude of the torque on the rotary table, the flow rate of the drilling mud at the inlet and outlet of the well, and the mud level in the suction tanks shall be within the driller's field of view and shall be recorded by electronic means ensuring the possibility of storing the information for not less than 3 months and transmitting it to Rostechnadzor.
360. When drilling directional and horizontal wells, the following shall be monitored: the azimuth and the inclination angle of the wellbore; the spatial position of the wellbore; the relative position of the wellbores of the well being drilled and of the previously drilled neighbouring wells. The frequency of monitoring is established by the drilling contractor, taking into account the requirements of the working design.
361. The method and modes of drilling, the type of rock-cutting tool, and the outflow velocity of the mud jet from the bit nozzles shall comply with the working design.
362. Work involving regulation of the differential pressure in the well-formation system, including underbalanced and balanced drilling, using gaseous agents and aerated flushing fluids, shall be performed in accordance with the working design.
363. The drilling organisation shall develop actions for the prevention and elimination of typical complications.
364. The suspension of wells during drilling operations is carried out in the manner provided for by the requirements of Chapter LVIII of these Rules. In doing so, it is necessary to: run the drill pipes into the well to the setting depth of the technical casing (conductor). Screw a ball cock and a check valve onto the upper drill pipe; seal off the annular space of the well by means of the preventer assembly; run the kelly with the swivel into the rathole. Disconnect the drilling hose from the swivel; lay the hook and the travelling block (hook-block) on the floor of the rig platform. Release the brakes of the drawworks and the auxiliary winch; release the air from the pneumatic system of the drilling rig; drain the liquid from the discharge pipeline and blow it out with compressed air. Remove the suction and discharge valves from the drilling pump; de-energise the drilling rig (in the case of a diesel drive, shut off the fuel line); ensure security of the facility and monitoring of the well pressure at the wellhead. The wellbore shall be periodically gauged or reamed to the bottomhole. The frequency of these operations is established by the drilling organisation.
365. When carrying out repair and isolation work, perforation of the casing strings in the interval of possible rupture of the formation by the pressure of gas or oil (after their inflow has been induced) or of the column of drilling mud shall be prohibited.
366. Work to free a stuck drilling tool or casing strings using explosive materials (detonating cords, torpedoes and other specialised equipment) shall be carried out according to a plan developed and agreed jointly by the drilling organisation and an organisation which, in accordance with Federal Law No. 99-FZ of 4 May 2011 "On the Licensing of Certain Types of Activity" (Collection of Legislation of the Russian Federation, 2011, No. 19, item 2716; 2020, No. 31, item 5029), holds a licence for carrying out this type of work, taking into account the safety requirements for blasting operations.
367. Before running non-standard elements of the drill string into the well, a sketch of this tool shall be drawn up, indicating the dimensions and its location in the drill string assembly, recorded in the drilling log and in the daily report of the drilling crew.
368. For drilling out the internal parts of the process equipment, the coupling devices and the cement plugs in the casing strings, bottomhole assemblies and technologies that protect the casing strings from damage shall be used.
369. The conduct of tripping operations shall be performed using mechanisms for making up and breaking out pipes and special fixtures. Reliable communication shall be ensured between the driller and the derrickman, including by establishing a clear procedure for the exchange of signals between the derrickman and the driller.
370. Making up and breaking out the threaded connections of drill pipes and other elements of the drill string assembly by rotation of the rotary table shall be prohibited.
371. When running in the drill string, it shall be prohibited to engage the slips before the string has come to a complete stop.
372. Bringing the manual and automatic tongs to the string of drill (casing) pipes is permitted only after they have been set on the slips or in the elevator.
373. The speeds of tripping operations, taking into account the permissible fluctuation of the hydrodynamic pressure, and the duration of the intermediate flushings are regulated by the working design. Where the rheological properties of the drilling mud and the drill string assemblies deviate from the design ones, corrections shall be made to the process procedure for the speed of tripping operations, taking into account the permissible fluctuations of the hydrodynamic pressure.
374. When pulling out the drill string, the outer surface of the pipes shall be cleaned of drilling mud by means of special fixtures (wipers).
375. At the wellhead, a device shall be installed that prevents the falling of foreign objects into the well when there is no pipe string in it.
376. The stands of drill pipes and drill collars set in the derrick shall be secured against falling out from behind the finger.
377. It shall be prohibited to carry out tripping operations in the case of: the absence or malfunction of the lift limiter of the travelling block or of the permissible-hook-load limiter; malfunction of the tripping equipment and tools; an incomplete tour complement for work on the specific rig; an inclination angle of the stands of 2 degrees, for drilling rigs with an automated tripping operations system (ATS) - 3 degrees, for offshore rigs with mechanised stand handling - 8 degrees; a wind speed of more than 20 m/s; a loss of visibility of more than 20 metres in fog and snowfall.
378. The drilling crew shall, each shift, carry out a preventive inspection of the hoisting equipment (the drawworks, the travelling block, the hook, the hook-block, the swivel, the links, the drilling line and the devices for its fastening, the elevators, the spiders, the safety devices, the interlocks and other equipment), with an entry in the equipment inspection log.
379. During tripping operations it shall be prohibited to: be within the radius (zone) of action of the automatic and manual tongs and of the working and safety ropes; open and close the elevator before the travelling block has come to a complete stop; supply drill pipe stands from the setback and set them without using special fixtures; use an inverted elevator.
380. The modes of lifting an unloaded elevator, and also the removal of the string of drill and casing pipes from the rotary table, shall preclude the possibility of swinging of the travelling system.
381. When using a pipe breakout device, the tension rope and the tong shall be located in the same horizontal plane. The rope shall be securely fastened to the rod of the pipe breakout device. Operation of the pipe breakout device without a guiding swivel roller shall be prohibited.
382. During drilling operations and after completion of a drilling run, breaking off the bottomhole and pulling out of a freshly drilled wellbore shall be performed at a reduced speed of the drawworks.
383. It shall be prohibited to raise or lower the travelling block when the boom of the pipe feeding mechanism is extended.
384. The type and properties of the drilling mud shall comply with the working design and, in combination with the process actions, shall ensure trouble-free conditions for carrying out drilling operations.
385. The drilling contractor shall exercise control over the availability of documents confirming the conformity of the chemical reagents and materials used for the preparation of process and flushing fluids.
386. The density of the drilling mud when penetrating gas-, oil- and water-bearing deposits shall be determined for the top of the horizon with the maximum formation pressure gradient in the interval of compatible drilling conditions.
387. The design solutions for the selection of the density of the drilling mud shall provide for the creation, by the column of mud, of a hydrostatic pressure on the bottomhole of the well and on the penetration of the productive horizon, exceeding the design formation pressures by an amount of not less than: 10 per cent for wells with a vertical depth of up to 1200 metres (intervals from 0 to 1200 metres); 5 per cent for intervals from 1200 metres vertically to the design depth.
388. In necessary cases, a higher density of the drilling mud may be established in the working design, but in doing so the maximum permissible overbalance (taking into account the hydrodynamic loads) shall preclude the possibility of hydraulic fracturing of the rock or loss of the mud at any depth of the interval of compatible drilling conditions.
389. In intervals prone to loss of stability of the wellbore walls and to rock flow, the parameters of the drilling mud are established on the basis of the need to ensure the stability of the well walls. In doing so, the counter-pressure on the horizons during circulation shall not exceed the formation fracturing pressure for the entire interval of compatible drilling conditions.
390. When drilling with a bottomhole pressure lower than the formation pressure, the drawdown on the well walls shall be not more than 15 per cent of the effective skeletal stresses (the difference between the rock pressure and the pore pressure of the rocks).
391. By a joint decision of the designer, the customer and the contractor, deviations from the requirements of paragraph 387 of these Rules are permitted in the following cases: in the case of losses of the drilling mud during drilling (with or without return of circulation); in the design and conduct of drilling operations with penetration of productive formations with bottomhole pressures approaching the formation pressure (balanced) or below the formation pressure (underbalanced).
392. Deviation of the density of the drilling mud (freed of gas) pumped into the well during circulation by more than +/- 0.03 g/cm3 from the value established by the working design shall not be permitted (except in cases of eliminating gas, oil and water shows and complications).
393. The treatment and preparation of the drilling mud are carried out in accordance with the working design and the developed formulation; in doing so, the requirements of Chapter XXXIII of these Rules and the instructions for the safe handling of chemical reagents shall be followed, and (where necessary) protective equipment shall be used.
394. When carrying out drilling operations, a reserve of drilling mud of not less than two well volumes shall be maintained: one in the tanks of the drilling rig, and the second may be held in the form of materials and chemical reagents for its prompt preparation.
395. Increasing the density of the drilling mud in the well by pumping in separate portions of weighted mud shall be prohibited (except in cases of eliminating gas, oil and water shows and pumping slugs of drilling mud of increased viscosity and lower rheological properties to remove the cuttings bed in the horizontal section of the wellbore, pumping slugs of drilling mud of increased density during hydraulic cleaning of the wellbore of sloughed cuttings, and also when drilling without circulation returns). When drilling offshore wells, to compensate for the change in hydrostatic pressure before disconnecting the drilling riser, the pumping of weighted mud in the volumes established by the working design for the drilling operations or by the well conservation documentation may be carried out.
396. When using hydrocarbon-based drilling muds (lime-bitumen, invert-emulsion and others), the drilling contractor shall develop labour protection actions to prevent contamination of workplaces and gas contamination of the air environment. The locations determined by the working design where, during the performance of work, the release of hazardous and harmful gases into the working area is possible shall be equipped with automatic gas analysers; if gas contamination appears, the causes shall be identified and measures taken to eliminate it. At a concentration of hydrocarbon vapours exceeding 300 mg/m3, work shall be suspended and people withdrawn from the hazardous area.
397. When using hydrocarbon-based drilling muds whose flash point does not exceed the maximum expected temperature of the mud at the wellhead by 50 °C, sensors monitoring the concentration limits of flame propagation shall be installed in accordance with the requirements of paragraph 163 of these Rules.
398. The cleaning of the drilling mud of drilled cuttings and gas, and the decontamination of cuttings during their disposal, shall be carried out by a set of means provided for by the working design for well drilling.
399. The cementing materials used in the performance of drilling operations shall have certificates confirming their quality. The properties of the cementing materials and of the cement stone formed from them shall conform to the working design.
400. The running-in and cementing of casing strings are carried out according to plans developed by the drilling organisation and agreed with the subsoil user (customer). Attached to the plan are the initial data for calculating the casing strings, the strength safety factors used, the results of calculating the casing strings (the string layout) and their cementing, the analysis of the components of the cement mixture, and also the certificate of readiness of the well and the drilling rig for running in and cementing the string.
401. In the event that the casing string is not run to the intended depth during the performance of drilling operations, an operational decision to change the provisions of the working design is made after agreement with the customer and subsequent notification of the design organisation.
402. The planning of the process of casing the wellbore shall be carried out on the basis of information obtained from the results of geophysical well surveys during drilling and (or) logging operations.
403. The use of components of the cement mixture without carrying out a preliminary laboratory analysis for the conditions of the forthcoming cementing of the string shall be prohibited.
404. To preserve the natural permeability of the porous and porous-fractured reservoirs of the productive deposits, the cement slurries shall have the minimum possible filtration. The total mineralisation of the cement slurries shall be close to the mineralisation of the drilling muds used when opening up the productive horizons.
405. The calculated duration of the process of cementing the casing string shall not exceed 75 per cent of the time to the onset of thickening of the cement slurry according to the laboratory analysis.
406. The selection of cementing materials and slurries based on them shall be carried out taking into account the following requirements: the cementing material and the stone formed from it shall conform to the range of static temperatures in the well over the entire cementing interval; the formulation of the cement slurry is selected according to the dynamic temperature and pressure expected in the cemented interval of the well; the density of the cement slurry shall be not lower than the density of the drilling mud and the buffer fluid. The limitation of the upper limit of the cement slurry density, all other conditions being equal, is the prevention of fracturing of the rocks under the action of hydrodynamic pressure during cementing. Where aggressive media are present in the cemented interval, the cement stone shall be corrosion-resistant to the action of these media and resistant to deformation during perforation and hydraulic fracturing.
407. Within the cementing interval, casing strings shall be equipped with elements of the process fittings, the range and quantity of which are determined by the working design for well drilling, while the installation locations are specified taking into account the actual condition of the wellbore according to the geophysical well survey data.
408. The running-in schedule of the casing strings and the hydraulic cementing programme shall be calculated and carried out in such a way as to ensure the minimum possible overbalance on the productive horizons and to prevent complications associated with fracturing of the rocks and loss of circulation. During cementing, continuous instrumental recording of the parameters characterising this process shall be ensured.
409. Conductor pipes and surface casings are cemented up to the wellhead. In the underlying part of the stratigraphic section, the following shall be cemented: productive horizons, except those designed for production with an open hole; productive deposits not subject to production, including those with non-commercial reserves; depleted horizons; pressure water-bearing horizons with an anomaly coefficient greater than 1.3; permeable water-bearing horizons that are under development or planned for development; horizons of secondary (man-made) accumulations of oil and gas; intervals composed of plastic rocks prone to deformation; intervals whose rocks or the products of their saturation are capable of causing accelerated corrosion of the casing pipes.
410. The height of rise of the cement slurry along the length of the wellbore above the top of the productive horizons, above the stage cementing device or the joint connecting the sections of the casing strings, and also above the shoe of the previous casing string, in oil wells shall be not less than 150 metres, and in gas wells not less than 500 metres. When inter-casing sealing devices are included in the casing strings, they shall be located at a height of not less than 75 metres for oil wells and 250 metres for gas wells above the shoe of the previous casing string, the stage cementing device and the joint connecting the sections of the casing strings. In such cases, the height of rise of the cement slurry is limited by the height of the location of the inter-casing sealing device. It shall not be permitted to begin equipping the wellhead before the completion of waiting on cement and the determination of the height of cement rise behind the casing string.
411. A discontinuity of the cement stone in the cementing intervals shall not be permitted. The exceptions are cases of counter-cementing under conditions of loss of circulation.
412. The total design height of rise of the cement slurry behind the casing strings shall ensure: the excess, during waiting on cement, of the hydrostatic pressures of the composite column of drilling mud and cement mixing fluid over the formation pressures of the overlapped fluid-bearing horizons; the exclusion of fracturing of the rocks or the development of intensive loss of circulation of the mud; the possibility of setting down the casing string onto the cement ring for the installation of the casing head. In the case of stage cementing and running strings in sections, the lower and intermediate stages and sections of the casing strings shall be cemented over their entire length.
413. When a loss-of-circulation zone drilled without circulation returns is covered by a surface casing or an intermediate casing, the cement slurries are raised to the bottom of the loss formation, followed (after waiting on cement) by counter-cementing through the inter-casing space. It shall be prohibited to begin running technical and production casings into a well complicated by losses of drilling mud with simultaneous fluid shows, sloughing, caving, overpulls and set-downs of the drill string, until the complications have been eliminated.
414. During the period of waiting on cement, the casing string shall be left suspended.
415. The cementing head, before it is put into operation and thereafter at the intervals established by the manufacturer's documentation, shall be pressure-tested at a pressure 1.5 times the maximum design working pressure during cementing of the well.
416. The injection pipelines for cementing, before the start of the process, shall be pressure-tested to one and a half times the expected working pressure. The procedure for the cementing work is established by the work plan developed by the contractor performing the cementing work, agreed with the drilling contractor and approved by the subsoil user (customer).
417. To ensure the safety of the performance of work during the casing of wells, the units shall be installed on a previously prepared site, and the following distances shall be observed: from the wellhead to the block manifolds and units - not less than 10 metres; from the block manifolds to the units - not less than 5 metres; between the cementing units and the cement mixing machines - not less than 1.5 metres. The cabins of the mobile units shall be located on the side opposite to the well being cemented.
418. To determine the actual condition of the cement stone behind the casing strings, geophysical well surveys are carried out. The use of other methods of investigating the condition of the cement stone behind the casing strings shall be substantiated in the working design for well drilling.
419. Reports on the results of running the casing string and its cementing (certificates, charts, string measurements, the results of geophysical well surveys and other investigations of the condition of the cement stone, and other documents) are included in the well file (passport), which is kept throughout the entire period of its operation.
420. All surface casings, intermediate and production casings carrying blowout prevention equipment, after the installation of cement bridge plugs to isolate the tested objects and after the completion of waiting on cement, shall be subjected to a tightness and cementing-quality test. All the design parameters of the tests are established taking into account the actual condition of the well. The tightness testing of casing strings may be carried out at the moment of seating the displacement plug on the TsKOD and by creating the necessary pressure by means of the cementing unit.
421. The tightness testing of surface casings and intermediate casings is carried out by pressure testing with them filled with a fluid that is the base of the drilling mud used (mineralised water, liquid hydrocarbons), from the wellhead to a depth of 20 to 25 metres, and in the remaining part - with the drilling mud used to displace the cementing mixture. The production casing is tested for tightness by pressure testing with drilling mud or industrial water (including mineralised or sea water). In wells at whose wellhead there may be no excess pressure, the production casing shall additionally be tested for tightness by lowering the water level to the dynamic level under mechanised oil production.
422. During the tightness testing of the strings by the pressure-testing method, the internal pressure created on the pipes shall exceed by not less than 10 per cent the possible pressure arising during the elimination of gas, oil and water shows and open blowouts, and also during the testing and operation of the well. The string is considered tight if, over 30 minutes, the pressure-testing pressure has decreased by not more than 0.5 MPa. The presence of the customer's representative at the pressure testing is mandatory. The results of the pressure testing are documented by a certificate signed by the representatives of the customer and of the work contractor.
423. After drilling out the cement plug and passing out from under the shoe by 1 to 3 metres, pressure testing of the near-shoe zone of the open wellbore is carried out. The pressure-testing pressure is determined by the need to ensure the tightness of the cement support behind the casing shoe when the wellhead is closed during an open blowout. The results of the pressure testing are documented by a certificate signed by the representatives of the customer and of the work contractor.
424. The method, parameters and technology of pressure testing the inter-casing space are established by the working design. At the wellhead, the inter-casing space is pressure-tested with a fluid that is the base of the drilling mud used (mineralised water, liquid hydrocarbons) to a pressure not exceeding the residual strength of the previous string and the compressive strength of the cement stone of the annular space. The inter-casing space is considered tight if, over 30 minutes, the pressure-testing pressure has decreased by not more than 0.5 MPa. The presence of the customer's representative at the pressure testing is mandatory. By agreement with the subsoil user (customer), pressure testing of the inter-casing space with air may be carried out. The results of the pressure testing are documented by a certificate signed by the representatives of the customer and of the work contractor.
425. In all cases, the density of the pressure-testing fluid shall be sufficient to compensate for excess external pressures to a level preventing the possibility of collapse of the casing strings under external pressure.
426. Drilling and workover organisations shall develop instructions for the installation and operation of blowout prevention equipment in accordance with the equipment used, the work technology and the manufacturers' instructions for installation, maintenance, operation and repair.
427. On the surface casing and intermediate casings below which, during drilling, the opening up of gas-, oil- and water-showing deposits is possible, and also on the production casing when work associated with opening up the productive horizon and other work with an opened productive formation is carried out in it, blowout prevention equipment is installed. The casing strings shall be tied together by casing heads. The working pressure of the casing head shall be not less than the tightness pressure-testing pressure of the casing string, calculated at each stage of well drilling on the basis of the complete replacement in the well of the drilling mud by formation fluid or a gas-liquid mixture and the sealing of the wellhead during the elimination of an open blowout. The temperature operating regime of the casing head shall be not lower than the values of the design decisions. In wells drilled into a studied section represented by oil- and water-bearing formations (with dissolved gas) with a formation pressure not exceeding the hydrostatic pressure, the tie-in of the casing strings without the use of a casing head may be carried out, provided that the casing strings are cemented over their entire length.
428. The blowout preventer assembly, the manifold (choke and kill lines), the hydraulic control system of the preventers, the choke control console, and the separator (trap-flare unit) are selected depending on the specific mining and geological conditions, taking into account the possibility of performing the following process operations: sealing the wellhead with the drill string run in and without it; washing the formation fluid that has entered the well out to the surface; suspending the drill pipe string on the preventer rams after it is closed; shearing the drill string; monitoring the condition of the well during killing; reciprocating the drill string to prevent its sticking; running in or pulling out part or all of the drill string with the wellhead sealed.
429. The selection of the type of blowout prevention equipment and casing head, and the scheme of installation and tie-in of the blowout prevention equipment and of the kill and choke blocks, are carried out by the design organisation and agreed with the customer. In doing so, the following provisions shall be followed: when opening up a studied section with a formation pressure not exceeding the hydrostatic pressure, preventers are installed, the type and number of which are determined by the design for the drilling operations; three or four preventers, including one annular preventer, are installed on the well when opening up gas, oil and water horizons with abnormally high formation pressure. The need to install a preventer with shear rams, where the expected excess pressure at the wellhead is below 35 MPa and the volumetric content of hydrogen sulphide is up to 6 per cent, is determined by the design organisation on the basis of the formation characteristics (fluid composition, formation pressure, porosity, permeability, flow rate); four preventers, including one preventer with shear rams and one annular preventer, are installed at the wellhead in the cases of: (a) opening up formations with abnormally high formation pressure (that is, a pressure exceeding the hydrostatic pressure by 1.3 times) and a volumetric content of hydrogen sulphide of more than 6 per cent, and also with the presence of hydrogen sulphide of up to 6 per cent and an excess pressure at the wellhead of more than 35 MPa; (b) the use of the technology of running in and pulling out pipes under the excess pressure of a sealed wellhead. In the cases of opening up a studied section with abnormally low formation pressure, represented by oil and water formations (with dissolved gas), the preventer stack may not be installed. At fields at a late stage of development, characterised by a low value of gas saturation of the oil (low gas factor) and a mechanised method of production, where the static and dynamic level of the fluid is below the wellhead, the composition of the blowout preventer assembly, the types of preventers, and the need to install a casing head or their analogues for sealing the wellheads are established and substantiated in the working designs for the drilling operations.
430. On land, the discharge lines to the flares from the kill and choke blocks shall be fastened on special supports and directed away from carriageways, power transmission lines, boiler houses and other industrial and domestic structures, with a downward slope from the wellhead. The free ends of the discharge lines shall have a length of not more than 1.5 metres. The length of the lines from the kill and choke blocks to the free ends of the discharge lines shall be: for oil wells with a gas factor of less than 200 m3/t - not less than 30 metres; for oil wells with a gas factor of more than 200 m3/t, and for gas and exploration wells - not less than 100 metres; for all prospecting-appraisal and exploration wells - not less than 50 metres. The lines and the valves installed on them shall have an internal diameter equal to the internal diameter of the branches of the cross; after the valve block, an increase of their diameter by not more than 30 mm may be carried out. The distance from the ends of the flow manifold to all communications and structures not belonging to the drilling rig facilities shall be not less than 100 metres for all categories of wells. For wells constructed from a fill foundation and on confined sites, the length of the lines from the kill and choke blocks shall be established by the contractor in agreement with the customer. It is permitted to direct the discharge lines to one side using assemblies and parts having passports of the established form.
431. On wells where the expected wellhead pressure exceeds 70 MPa, a factory-made block with three adjustable chokes is installed - two with remote control and one with manual control. In all other cases, the installation of adjustable chokes with remote control is carried out depending on the specific conditions and is decided by the management of the organisation upon approval, in accordance with the established procedure, of the scheme of tie-in and installation of the blowout prevention equipment.
432. The pressure gauges installed on the choke and kill blocks shall have an upper limit of the measurement range exceeding by 30 per cent the pressure of the joint pressure testing of the casing string and the blowout prevention equipment. The charging system of the hydraulic accumulator shall include a device for the automatic shut-off of the pump when the nominal working pressure is reached in it.
433. The blowout prevention equipment shall be assembled from factory-made assemblies and parts of domestic or imported supply. The use of individual assemblies and parts manufactured at the organisation's production service bases in accordance with the manufacturer's design and construction documentation may be carried out. The manufactured assemblies and parts shall have technical passports.
434. To control the preventers and the hydraulic valves, a main and an auxiliary console are installed: the main control console - at a distance of not less than 10 metres from the wellhead in a convenient and safe place; the auxiliary one - directly next to the driller's console. It is switched into the operational readiness mode before opening up productive and gas-, oil- and water-showing formations. The oil lines of the hydraulic control system of the blowout prevention equipment shall be pressure-tested in accordance with the operating instructions, be tight and protected against possible damage. The design of the control console shall provide for an audible or light alarm when the level of the working fluid in the tank falls below the permissible level. The hydraulic control system shall ensure the possibility of releasing air.
435. The handwheels for manually locking the preventer rams shall be installed in an easily accessible place and have explosion-proof lighting and a shelter. On the wall of the shelter there shall be applied: arrows showing the direction of rotation of the handwheels; the number of turns required to close the preventers; marks whose alignment with the marks on the spokes of the handwheels corresponds to the complete closure of the preventers; and the size of the rams. On the valve in front of the choke, a plate shall be fixed indicating the permissible pressure for the wellhead, the permissible pressure for the weakest section of the well, and the density of the mud from which this pressure was determined. Each drilling rig is provided with portable lamps and emergency lighting at a voltage of not more than 12 V for lighting the blowout prevention equipment, in the deflector shields, at the main and auxiliary preventer control consoles, at the drilling-tool weight indicator panel, at the choke block and at the kill block.
436. When opening up reservoirs saturated with oil and gas, two ball valves shall be available at the rig: one is installed between the kelly and its safety sub, and the second is a spare. If a top drive is used, an automatic ball valve with the possibility of manual control shall be included in it. When opening up gas formations with abnormally high pressure and horizons containing hydrogen sulphide, there shall be three valves at the rig: the first ball valve is installed between the kelly and the swivel, the second - between the kelly and its safety sub, and the third is a spare. All ball valves shall be in the open state. In addition to the ball valves, two non-return valves with a device for setting them in the open position shall be available at the rig: the first valve is the working one, the second the reserve one. The ball valves and non-return valves shall have technical passports and information on the performance of flaw detection. Pressure testing of the ball valves and non-return valves is carried out once every 6 months. Records of the operating time of the ball valves and non-return valves are kept throughout the entire period of operation, up until their decommissioning.
437. The preventers, together with the crosses and master valves, and the blowout-prevention-equipment manifold (the kill and choke blocks), before installation at the wellhead, are pressure-tested with water to the working pressure indicated in the technical passport. After a repair involving welding and machining of the body, the preventers are pressure-tested to the test pressure. The blowout preventer assembly with shear, pipe and blind rams shall be pressure-tested on a stand to the working pressure with the rams closed, and the operability of the preventer checked by opening and closing the rams. The results of the tests carried out shall be confirmed by the corresponding certificates.
438. After installation and before drilling out the cement plug, the blowout preventer assembly, up to the end valves of the high-pressure manifolds, shall be pressure-tested with water or inert gas to the casing-string pressure-testing pressure indicated in the working design. The blowout prevention equipment is considered tight if, over 30 minutes, the pressure-testing pressure has decreased by not more than 5 kgf/cm2 (0.5 MPa). The presence of the customer's representative at the pressure testing is mandatory. The flow lines after the end valves are pressure-tested with water to a pressure of: 50 kgf/cm2 (5 MPa) - for blowout prevention equipment rated for a pressure of up to 210 kgf/cm2 (21 MPa); 100 kgf/cm2 (10 MPa) - for blowout prevention equipment rated for a pressure above 210 kgf/cm2 (21 MPa). The results of the pressure testing are documented by a certificate signed by the representatives of the customer and of the work contractor.
439. After the casing of the well, where there are productive or water-pressure formations in the underlying section, further drilling of the well may be continued after the installation and pressure testing of the blowout preventer assembly together with the casing string and the pressure testing of the cement ring behind the casing string.
440. The preventers shall be periodically checked for closing and opening. The frequency of checking is established by the drilling organisation, but not less than once a month. The working pressure of the preventer block and the manifold shall be not less than the tightness pressure-testing pressure of the string, calculated at each stage of well construction on the basis of the complete replacement in the well of the drilling mud by formation fluid and the sealing of the wellhead during an open blowout.
441. When replacing failed parts of the preventer or one of the assemblies of the preventer stack, or changing the rams at the wellhead, the blowout preventer assembly is subjected to additional pressure testing to the value of the casing-string test pressure. The results of the pressure testing are documented by a certificate.
442. The rams of the preventers installed at the wellhead shall correspond to the diameter of the drill pipes used. Blind rams are installed in the lower preventer when there is no preventer with shear rams in the stack.
443. In cases where a multi-size drilling tool assembly is used for drilling, a special pressure-tested steel pipe with strength characteristics corresponding to the upper section of the drill string used shall be available on the pipe rack. The special pipe shall be painted red and have a mark applied with white oil paint, on the alignment of which with the rotary table the tool joint of the pipe will be 300 to 400 mm below the preventer rams. The diameter of the special pipe shall correspond to the diameter of the preventer rams. Onto the special pipe, subs for the other pipe diameters used in the assembly shall be screwed by hand. Onto the coupling of the pipe, a ball valve shall be screwed and secured with machine tongs. At the wellhead, the special pipe with the ball valve screwed on is pressure-tested to the pressure of the joint pressure testing of the blowout prevention equipment with the casing string.
444. When running casing strings into wells with opened high-pressure formations and where the installed annular preventer does not correspond to the expected wellhead pressures, the rams of one of the preventers are replaced with rams corresponding to the diameter of the casing string being run, or a special (steel, with the corresponding strength characteristics) drill pipe with a sub for the casing pipe and a ball valve in the open position, pressure-tested to the corresponding pressure, shall be present on the receiving pipe rack.
445. For unimpeded access of workers to the blowout prevention equipment installed at the wellhead, a solid decking shall be made under the rig.
446. All schemes of blowout prevention tie-in of the wellhead shall, in the upper part, include a flange spool, a split funnel and a trough to facilitate the work of eliminating open blowouts.
447. The blowout prevention equipment of a hazardous production facility of the offshore oil and gas complex shall include not less than four preventers, including one with shear rams and one annular preventer. The working pressure of the blowout-prevention-equipment preventers shall exceed by not less than 15 per cent the expected pressure at the wellhead when closing during flowing.
448. The control console of the preventers forming part of the blowout prevention equipment of a hazardous production facility of the offshore oil and gas complex provides for their remote closing and opening. The preventer with shear rams provides for the shearing of the strongest pipe intended to be run into the well. The volume of the hydraulic accumulator provides a double full cycle of opening and closing of the preventers in the event of a power failure.
449. On a floating drilling rig with a subsea wellhead location, pressure testing of each preventer in the subsea blowout prevention equipment stack is carried out on a stand to the working pressure. Before running in, a check of the operability of the preventers is carried out. After each string run in, pressure testing of the ram preventers and the annular preventer to the working pressure is carried out using a test packer, and pressure testing of the preventer with blind shear rams to the pressure-testing pressure of the production casing.
450. Trap-flare and separation units are placed on the open sites of the MSP, PBU, ME and PTK in accordance with the expected operating conditions in terms of pressure and capacity. When carrying out work under low-temperature conditions, the kill and choke lines of the blowout prevention equipment are filled with non-freezing fluid. The blowout prevention manifold, together with the line from the drilling-mud separator to the trough, is equipped with a device for blowing through.
451. When carrying out tripping operations on a well forming part of a hazardous production facility of the offshore oil and gas complex, continuous automatic measurement and regulation of the volume of drilling mud in the well is carried out.
452. In the event of a gas, oil and water show on a well forming part of a hazardous production facility of the offshore oil and gas complex, the degassed fluid enters the separation and degassing system through the nozzle line. The separated gas is directed to discharge, and the fluid - into the circulation system for its treatment.
453. The organisation operating an MSP, PBU, ME and PTK, where the PVO is located subsea, develops an instruction on the planned and emergency disconnection of the PPVO, taking into account the results of the safe operation of the drilling riser and its disconnections at various sea depths and at various angles of its deviation from the vertical in the lower connector.
454. Before opening a formation or several formations with possible fluid shows, measures to prevent GNVP shall be developed and implemented, and the following shall be carried out: briefing of the drilling crew members on the practical actions for the elimination of GNVP in accordance with the special sections of the PMLA developed in accordance with Appendix No. 6 to these Rules; checking of the condition of the drilling rig, the PVO, the tools and the appliances; the "Blowout" drill, with the further frequency of drills established by the drilling organisation; checking of the presence in the working and reserve tanks of the required quantity of flushing fluid, as well as of the stock of materials and chemical reagents necessary in the event of GNVP for the preparation of flushing fluid in accordance with the working design; assessment of the facility's readiness for prompt weighting-up of the drilling mud and replenishment of its stocks by preparation or delivery to the drilling rig.
455. On detecting GNVP, the drilling watch shall seal the wellhead, inform the management of the drilling organisation, the blowout prevention service or the PASF of this and act in accordance with the PMLA. After sealing, the readings of the pressure gauges on the standpipe and in the annulus, the time of the onset of the show and the weight of the string on the hook shall be recorded.
456. After closing the preventers in the event of GNVP, monitoring shall be established for the possible occurrence of griffons around the well and of leaks (of fluid, of gas) in the connections and components of the PVO.
457. To prevent GNVP and caving of the well walls while the drill pipe string is being tripped out, the well shall be topped up with drilling mud. The topping-up regime shall ensure that the mud level in the well is maintained close to its wellhead. The maximum permissible lowering of the mud level is established by the working design, taking into account the tolerances under paragraph 387 of these Rules. The properties of the drilling mud topped up into the well shall not differ from those of the mud already in it.
458. The volumes of mud displaced from the well when running in the drill pipe and topped up when tripping it out shall be monitored and compared with the volume of metal of the drill-string pipes tripped out or run in. If the difference between the volume of drilling mud topped up and the volume of metal of the pipes tripped out exceeds 0.5 m3, tripping out shall be stopped and measures shall be taken to seal the wellhead. The receiving tanks shall be equipped with fluid-level indicators.
459. Before and after opening formations with abnormally high formation pressure, when circulation of the well is resumed after tripping operations, well logging, repair work and idle periods, monitoring of the density, viscosity and gas content of the drilling mud shall begin immediately after circulation is restored.
460. When opening gas-bearing horizons and during further deepening of the well (before running the next casing string), the drilling mud shall be monitored for gas saturation. Tripping out of the drill string before the properties of the drilling mud are levelled out over the entire circulation cycle shall be prohibited.
461. When drilling in productive formations, the rate of penetration shall be limited to values at which degassing of the drilling mud is ensured.
462. If the volumetric gas content in the drilling mud exceeds the background value by 5 per cent (by volume), measures shall be taken to degas it, to identify the causes of gas saturation of the mud (formation flow, gas ingress with the drilled cuttings, foaming and so on) and to eliminate them.
463. Tripping the drill string out of a well in which loss of drilling mud has occurred in the presence of GNVP is permitted only after the well has been filled up to the wellhead and there is no overflow for a period sufficient to trip the drill string out and in.
464. Drilling of wells with partial or total loss of drilling mud (water) and possible fluid shows is carried out in accordance with a special plan, which is agreed with the designer, the PASF and the customer.
465. When setting baths (oil, water, acid), the hydrostatic pressure of the column of drilling mud and bath fluid shall exceed the formation pressure. Where there is a probability of or a need for lowering the hydrostatic pressure below the formation pressure, operations to reciprocate the drill string shall be carried out with a sealed annulus and with a ball valve installed in the drill pipe, with the development and implementation of safety measures in accordance with the PMLA.
466. The technical devices, tools, materials, protective clothing, safety and personal protective equipment necessary for the elimination of GNVP and open blowouts, as specified by the design documentation, shall at all times be in full readiness at the warehouses of the organisations operating hazardous production facilities of the oil and gas complex.
467. Tripping the drill string out in the presence of a siphon or swabbing shall be prohibited. When they appear, tripping out shall be stopped and circulation with rotation and reciprocation of the drill pipe string shall be carried out. Where the siphon cannot be eliminated (clogging of the turbodrill or the bit with cuttings, or other causes), the pipe shall be tripped out at speeds at which equality of the extracted volumes of pipe metal, of fluid and of mud topped up into the well is ensured. Where swabbing cannot be eliminated (the presence of a mud pack on the bottom-hole assembly or a narrowing of the wellbore), tripping out shall be carried out with circulation and rotation of the drill pipe string.
468. Where formation fluid enters the well during tripping of the drill string out of an interval of open (uncased) wellbore, tripping out shall be stopped, the well shall be circulated for one cycle, the drill string shall be run down to the bottomhole, the well shall be circulated for not less than two cycles bringing all the parameters of the flushing fluid into conformity with the geological and technical programme (the cause of the entry of the formation fluid shall be determined and measures taken), after which the drill string shall be tripped out.
469. Work in the hazardous zone to eliminate an open blowout shall be carried out by the personnel of the PASF in accordance with special plans developed by the headquarters set up by the organisation operating the hazardous production facility. The headquarters bears full responsibility for implementing the developed actions.
470. Before opening a productive horizon, and where the exposed section contains oil- and gas-bearing deposits as well as other high-pressure horizons, warning notices shall be posted at the facility and all persons at work shall be warned that heightened attention is required in connection with the opening of the productive formation.
471. To prevent GNVP and open blowouts, the requirements of the instructions for the prevention of GNVP and open blowouts, developed by the organisation operating the hazardous production facility, shall be complied with.
472. In the event of an open blowout, the representative of the organisation carrying out the drilling operations notifies the PASF, the management of the operating organisation and the territorial body of Rostechnadzor of this.
473. In the event of an open blowout, the workers of the MNGK hazardous production facility shall: stop the internal combustion engines; disconnect the power and lighting supply lines of the emergency well; cease, within the gas-hazardous zone, all hot work, the use of steel tools, and any other actions capable of causing sparking.
474. During an open blowout, where a second drilling rig or hoisting units for well repair are present at the well cluster, their operation is stopped and measures are taken to cease hydrocarbon production from the wells in operation.
475. At the warehouses of the operating organisation, an emergency stock of equipment, tools, materials, protective clothing, communication devices and personal protective equipment necessary for the elimination of GNVP is kept in constant readiness.
476. In the event of an open blowout, the following shall be carried out: creation of water curtains between the accommodation block and the wellheads, at the collective life-saving appliances and at the drive of the hydraulic system for moving the derrick; preparation of the collective life-saving appliances and PPE for the evacuation of the workers. At the same time, the gas contamination of the premises of the accommodation and process blocks, of the evacuation routes and of the locations of the collective life-saving appliances is monitored.
477. The presence of persons not involved in the work to eliminate the open blowout shall not be permitted at the emergency facility or on the floating craft allocated to take part in the emergency work.
478. Before the emergency rescue vessel enters the zone of combustion, protective water spraying of the vessel's hull is switched on and measures are taken to prevent the danger of the vessel being surrounded by fire.
479. The actions of the workers on an alarm signal are defined in the PMLA and in the alarm schedules. The alarm schedules and an extract from the operational part of the PMLA are posted on each deck of the accommodation block and at the workplaces.
480. At the MNGK hazardous production facility, the following alarm schedules are provided for: the "General Ship Alarm" (which includes: "Firefighting", "Combating Water Ingress", "Combating an Emergency Petroleum-Product Spill", "Emergency Blowout"); "Man Overboard"; the "Boat Alarm" (abandonment of the MSP, ME, PBU or PTK). The alarm schedules specify the time for general evacuation. The alarm schedules shall be signed by the responsible person of the operating organisation and approved by its technical manager.
481. The evacuation of the workers by means of life-saving appliances is carried out on a special command (signal). The signal shall be duplicated by voice over the loudspeaker communication system in the Russian and English languages.
482. The command to evacuate the workers is given by the head of the MNGK hazardous production facility. After receiving the evacuation signal, the master of the MNGK hazardous production facility notifies the standby vessels and helicopters and, where necessary, gives the international distress signal.
483. The head and master of the MNGK hazardous production facility, the radio operator and the rescue teams are evacuated last, having made sure that no one has remained on the MSP, PBU, ME and PTK.
484. The checking of knowledge of the types of alarms is carried out during training and drill sessions on the MSP, PBU, ME and PTK at least once a week according to a schedule approved by the technical manager of the operating organisation.
485. In the event of an emergency situation on the MSP, PBU, ME or PTK and where the urgent transfer of the explosive materials to a rescue or standby vessel is impossible, the containers of explosive materials may (on the instruction of the head of the MNGK hazardous production facility) be dropped into the sea, in respect of which a report is subsequently drawn up stating the exact location of the sinking, the type of explosive materials, the weight and the nature of the packaging, and a notification is sent to the law-enforcement authorities and the hydrographic service.
486. If evacuation for the MNGK hazardous production facility is arranged using emergency rescue vessels, the latter are positioned at such a distance from the facilities (but no further than 5 nautical miles) that, under any hydrometeorological conditions, it is possible to approach the MSP, PBU, ME or PTK at the time set by the plan and to render assistance to the people on board it.
487. Emergency rescue vessels are equipped with a dynamic positioning system and fitted with devices for lifting people out of the water, with means for the localisation and elimination of emergency spills of oil and petroleum products, and for assisting distressed facilities in combating fires and water ingress.
488. The working design for the drilling of directional and horizontal wells shall contain the following provisions: actions for the prevention and early detection of GNVP; justification of the profile and the curvature intensity (the radius of curvature) of the wellbore on the basis of the specified length of the horizontal section in the productive formation; calculations of the additional bending loads on the casing, drill-pipe and tubing strings in the wellbore-curvature intervals; actions to ensure the failure-free and accident-free operation of the casing, drill-pipe and tubing strings under conditions of wellbore curvature in the zenith and azimuth directions; strength safety factors for the calculation of the casing strings and the conditions for ensuring the leak-tightness of their threaded connections; technical requirements for ensuring the passage inside the casing strings of pipes, tools and appliances for carrying out technological operations, of instruments, fishing tools and downhole equipment; actions to minimise wear of the casing strings during tripping and other operations and to prevent keyseat formation in the curvature intervals and the horizontal section; a hydraulics programme ensuring the transport of cuttings out of the horizontal section of the wellbore and the flushing-out of gas caps; justification of the method of casing the well in the intervals of intensive curvature and the horizontal section; the permissible loads on the well walls from the contact force of the drill pipe string at the places of intensive build-up of curvature.
489. The choice of the design of directional and horizontal wells shall be determined in accordance with the requirements established by Chapter XV of these Rules.
490. The circulation intensity at the beginning of each bit run shall ensure the removal of gas accumulations in the upper part of the low-angle or horizontal section (for example, at places of wellbore enlargement and at bends).
491. The choice of casing strings is determined in the working design for the drilling operations, taking into account calculations of the strength of the sections during the running and operation of the casing strings in the curvature intervals and horizontal sections, and of the external and internal pressures and tensions.
492. The choice of threaded connections and sealing means in the intervals of intensive wellbore curvature shall ensure the required strength characteristics of the casing string and the leak-tightness and reliability of the lining throughout the entire operating period of the well. The types of threaded connections and thread greases used are determined by the working design.
493. The choice of the outer diameter of the tool joints of the drill string and their design are carried out taking into account the design curvature intensity of the wellbore, with a view to minimising the loads on the well wall to prevent keyseat formation and to reduce wear of the casing strings.
494. When carrying out well-development operations, a stock of kill fluid in an amount of not less than two well volumes, kept directly at the well, or of materials for its prompt preparation, shall be maintained. Where prompt delivery and placement are possible, a stock of kill fluid in an amount of not less than two well volumes may be kept at the mud-preparation unit.
495. Well-development and well-testing operations may be commenced provided that the following conditions are ensured: the height to which the cement slurry has risen behind the production casing and the quality of the formed lining comply with the requirements of the working design for the drilling of the well; the production casing has been drifted and pressure-tested together with the casing head and the blowout preventer stack (the Christmas tree), and is leak-tight at a pressure exceeding by 10 per cent the maximum expected pressure at the wellhead; the wellhead with the Christmas tree or the blowout preventer stack and the discharge lines are equipped and connected in accordance with the diagram developed as part of the working design for the construction of the well, the requirements for which are established in paragraph 429 of these Rules; In the event of possible deviations in the height of the cement rise from the working design, the well-development and well-testing operations are carried out after agreement with the customer and the design organisation.
496. Before perforation of the production casing, the wellhead shall be equipped with the PVO in accordance with an approved diagram, and the well shall be filled with drilling mud (or a special fluid) conforming to the working design. In the event of opening, by perforation, gas, oil and water-bearing horizons with abnormally high formation pressure, the PVO shall be represented by a blowout preventer stack. The preparatory work before running the charged perforator into the well is carried out in accordance with the requirements of Chapter XLII of these Rules. Perforation of the productive formation at a lowered level or in a medium differing from the established requirements shall be carried out under conditions ensuring sealing of the wellhead in the event of GNVP. The technology and the procedure for carrying out such work are established by a special plan approved by the organisation operating the hazardous production facility (the customer) and agreed with the PASF.
497. During perforation, monitoring of the fluid level in the well shall be established by the performing authority.
498. Before being installed on the wellhead, the Christmas tree shall be pressure-tested to the value of the working pressure established by the manufacturer. The results of the pressure test at the wellhead are formalised by a report of a commission that includes a representative of the customer.
499. The set of well-development operations shall provide for measures ensuring: the prevention of plugging of the formation during secondary opening; the preservation of the formation skeleton in the bottomhole zone; the prevention of breakthrough of formation water and gas from the gas "cap"; thermal-hydro-gas-dynamic surveys to determine the quantitative and qualitative characteristics of the formation and its geological and physical parameters; the preservation, restoration or enhancement of the permeability of the bottomhole zone; the prevention of uncontrolled GNVP and open blowouts; the safe use of the subsoil and protection of the environment.
500. The stability of the bottomhole zone of the formation and the integrity of the cement stone are ensured by a permissible drawdown, the value of which is established by the customer, taking into account the design decisions and the actual characteristics of the formation opened by the well.
501. The inflow of fluid from the formation is induced by creating regulated drawdowns by means of: replacing the drilling mud with mud of lower density, technical water or degassed oil. In this case, the difference in the densities of the successively replaced fluids shall not be more than 0.5 - 0.6 g/cm3; where the density difference is greater, the rates of reduction of the back pressure on the formation shall be limited; the use of foam systems; the use of special technical means and technologies (for example, a jet pump).
502. Lowering of the fluid level in the production casing using air shall be prohibited. Inducing inflow by lowering the level in the production casing by swabbing, by using downhole pumps, or by injecting inert gas or natural gas from a neighbouring well is carried out in accordance with the work plan and is agreed with the customer.
503. Downhole measurements in wells with excess pressure at the wellhead shall be carried out using a lubricator whose technical characteristics correspond to the operating conditions of the well. Before installation, the lubricator shall be pressure-tested to the working pressure established by the manufacturer, and after installation - to the casing pressure-test pressure.
504. For each well to be developed, a work plan is drawn up and persons responsible for its implementation are appointed. The plan is approved by the technical manager of the organisation and is agreed with the customer.
505. Testing of wells during drilling by means of formation testers is carried out in accordance with a work plan providing for actions for the preparation of the wellbore, the treatment of the mud with anti-sticking additives, the value of the drawdown on the formation being tested, and the procedure for preparing the drill string and carrying out such an operation. The work plan is agreed with the customer and the geophysical organisation (in cases where it participates) and is approved by the technical manager of the drilling organisation.
506. Work with drill-string formation testers is permitted in wells where the drilling tools and pumps are in good working order. Depending on their objectives, formation tests may be carried out with or without the release of top-up fluid and formation fluid to the surface.
507. Before testing a well by means of a formation tester with the formation fluid brought out to the surface, it is necessary to: calculate the drill pipe string for the excess internal and external pressures that may arise during the testing; equip the drill string with a ball valve and a special wellhead head, having pressure-tested them to a pressure exceeding by 10 per cent the maximum expected during the operation; hook up the wellhead to the manifold of the drilling pumps and the discharge line of the blowout preventer stack; ensure the possibility of forward and reverse pumping of flushing fluid into the well; carry out a leak-tightness test of the casing string with the PVO; equip the wellhead with a working platform for the emergency closing of the emergency valve on the special wellhead head when tripping the drill string out with the hook-up elements above the rotary table; provide active ventilation at the drilling rig at the places where the formation fluid emerges.
508. Work with drill-string formation testers in wells that are not equipped with a blowout preventer stack shall be prohibited.
509. Work with drill-string formation testers under conditions of loss of flushing fluid and a weak well show shall be carried out in accordance with additional plans containing actions to ensure the accident-free performance and safety of the work and agreed with the PASF.
510. For the well-development and well-testing operations carried out, a daily report is drawn up in the form established by the organisation.
511. The technology of drilling operations in permafrost zones shall be determined by the permafrost and climatic conditions of the given region. The bringing of fields into development shall be preceded by the creation of detailed permafrost maps reflecting the surface conditions of the entire permafrost section. The territory of the field is divided into areas with permafrost parameters of the same type.
512. The siting of exploration and production wells shall be carried out mainly on areas with thawed and frozen rocks that are not subject to subsidence and deformation, and shall be based on data on the permafrost situation reflected on regional and detailed geocryological maps of the given area, compiled from the materials of surveys in monitoring and permafrost wells that have penetrated the entire permafrost interval.
513. The prevention of thawing and settlement of the rocks under the drilling equipment shall be ensured by maximum preservation of the surface cover.
514. The design of the wells shall ensure the reliable integrity of the wellhead and the near-wellbore space throughout the entire cycle of drilling operations and operation by using appropriate technical means and technological solutions.
515. Drilling of the wellbore for the conductor to a depth of 20 - 30 m shall be carried out with drilling mud that prevents cavern formation and thawing of the rocks, or with air blowing of the bottomhole. The conductor shall be cemented.
516. The surface casing shall cover the thickness of the rocks that are unstable upon thawing - the cryolithozone. The shoe shall be positioned below these rocks (by not less than 50 m) in stable deposits.
517. For the drilling of wells in permafrost zones, the use of water as the flushing fluid shall be prohibited.
518. To prevent cavern formation in permafrost intervals, high-viscosity polymer-clay and biopolymer muds with a controlled solids content, air or foam blowing of the bottomhole and, where necessary, bits of a diameter smaller than the nominal one with subsequent enlargement of the wellbore to the design value shall be used as flushing agents.
519. The thermal regime of drilling in permafrost intervals, as well as such indicators of the drilling mud as temperature, viscosity, static shear stress, filtration index and density, shall ensure a reduction of the weakening effect on the near-wellbore zone. The listed indicators shall be monitored and maintained within optimal limits.
520. For cementing the casing strings, cement for low and normal temperatures with a setting accelerator is used.
521. The temperature of the cement slurry shall be not lower than 8 - 10 degrees C to ensure its accelerated setting, but shall not exceed the temperature of the drilling mud during drilling for the casing.
522. When pressure-testing casing strings and inter-casing spaces, non-freezing fluids, including the buffer fluids used, shall be applied.
523. The set of actions to prevent collapse of the casing strings and emergency gas shows in wells in the event of their prolonged idle periods after the completion of drilling or during operation depends on the anticipated duration of the idle period (the time of back-freezing) and on the presence of freezing fluid in the behind-casing and inter-casing spaces. The set of actions is developed by the organisation carrying out the work in agreement with the subsoil user (the customer). Where freezing fluids are present in the inter-casing spaces of the well, periodic monitoring of their temperature by downhole thermometers shall be carried out. In the event of the temperature falling to dangerous values, periodic heating of the lining by pumping heated fluid or by gas offtakes shall be provided, or (in the case of long-term mothballing) freezing without perforation shall be carried out.
524. Work to induce inflow begins only after inspection of the condition of the well by downhole instruments (a thermometer, a pressure gauge), establishment of their passage along the entire wellbore and heating of the lining in the permafrost interval by pumping heated fluid through the run-in tubing.
525. These requirements apply to drilling operations from cluster sites and MNGK hazardous production facilities at oil, oil-and-gas, gas-condensate and gas fields.
526. When siting cluster sites on permafrost soils, the distance between the wellheads shall not be less than 1.2 of the diameter of thawing of the rocks around the wellheads.
527. To ensure industrial safety when works of different nature are combined in time (drilling, development, operation, installation of oil-and-gas production equipment and other works), the subsoil user (the customer) or its representative develops and approves regulations on the procedure for organising the safe performance of work. These actions are mandatory for compliance by all participants in the production process.
528. A responsible person in charge of the work, vested with the necessary powers, is appointed by the subsoil user (the customer) or its representative.
529. The regulations on the procedure for organising the safe performance of work shall provide for: the sequence of works and operations and the procedure for their commencement when combined in time; the operational and territorial delineation of the powers and responsibilities of all participants in the production processes; a system of operational monitoring of the progress and quality of the work and of compliance with industrial safety requirements; the procedure and conditions for interaction between the organisations and with the responsible person in charge of the work.
530. The procedure for the evacuation of people, transport and special equipment in the event of GNVP, open blowouts and other accidents shall be provided for by the PMLA and by the plans for the evacuation of people from the MNGK hazardous production facility.
531. When moving the derrick-and-drawworks block to a new point (position), and also when testing derricks and carrying out complex emergency work at the well, all work at the neighbouring facilities shall be stopped. People shall be removed from the hazardous zone (the height of the derrick plus 10 m) (except for the workers directly engaged in performing the work). At the MNGK hazardous production facility, the hazardous zone when moving the derrick-and-drawworks block to a new point (position), and also when testing derricks and carrying out complex emergency work at the well, is defined in the documentation of the owner of the MNGK hazardous production facility for the performance of such work.
532. Hazardous work shall be carried out under permits to work issued by the responsible person in charge of the work at the cluster site in accordance with the requirements of paragraphs 1076 - 1079 of these Rules.
533. Simultaneously with the drilling of the next well, work on the additional opening of productive formations, including by drilling horizontal branches from the main wellbore, may be carried out at previously drilled wells.
534. When dismantling the drilling rig or removing the derrick-and-drawworks and other blocks from the last well drilled in the cluster, and when transporting them from the cluster site, measures shall be developed to ensure the safe operation of the wells located in the hazardous zone, up to and including their shutdown. The handover of the next well by the drilling contractor and its acceptance by the customer are carried out after preliminary investigations of the quality of performance of the work and are formalised by a report signed by both parties.
535. The simultaneous drilling of two wells at the MNGK hazardous production facility is permitted, provided that the surface casing has been run in one of them and the PVO is installed on the wellhead.
536. When drilling production wells with two drilling rigs, the connection of their circulation systems is permitted, provided that the total volume of the circulation systems corresponds to the design requirements for the drilling of two wells.
537. During the simultaneous drilling and operation of wells on the MSP, PBU and ME, compliance with the following requirements is mandatory: flowing wells are equipped with a downhole shut-off valve and remotely controlled wellhead gate valves; oil and gas pipelines shall be fitted with in-line shut-off gate valves.
538. In the absence of substantiated design decisions on specific distances between the wellheads, the following requirements for the distances between the wellheads are observed: not less than 2.4 m for oil wells and not less than 3 m for gas and gas-condensate wells where the PVO for the drilling of wells is located on the upper tier and the gate valves of the Christmas trees of the wells in operation are on the lower tier of the topside of the platform; not less than 5 m where the PVO for the drilling of wells and the gate valves of the Christmas trees of the wells in operation are located on the same tier.
539. In the event of GNVP during drilling at one of the wells, all work at the other drilling rig is stopped and measures are taken to prevent complications. During the simultaneous drilling, workover or current repair and operation of wells, the operating organisation is notified of the GNVP that has occurred so that measures may be taken to cease oil production at the operating wells where necessary, as well as the organisation carrying out the workover or current repair of the wells. The management of the operating organisation and the drilling contractor are notified of the complication.
540. These requirements apply to drilling operations for the exploration and production of methane of coal deposits (areas, sites). These Rules do not apply to the drilling of wells from mine workings.
541. When drilling wells, the opening of the target watered coal seams on technical water is permitted.
542. Penetration of coal seams shall be carried out with bottomhole pressures approaching the formation pressure (at balance) or below the formation pressure (at depression).
543. The selection of the load-carrying capacity of the drilling rig shall be carried out in accordance with paragraphs 315 and 316 of these Rules.
544. Under conditions of a low probability of the occurrence of sticking and other complications associated with instability of the wellbore, the maximum load-carrying capacity of the drilling rig may be selected on the condition that the maximum design weight of the drill string and the greatest design weight of the casing strings will not exceed 0.75 and 0.9 of the "permissible hook load" respectively.
545. In the event of blowing the well with gas, aerosol, foam or aerated liquid, nitrogen, natural gas or spent exhaust gases of an internal combustion engine shall be used as the base gaseous agent.
546. The selection of the type of blowout prevention equipment and casing head is carried out by the design organisation and is agreed with the professional emergency rescue unit and the customer.
547. In cases of penetration of a studied section with abnormally low formation pressure, represented by water-encroached coal seams, the preventer assembly need not be installed, but the wellhead piping shall be agreed with the professional emergency rescue unit.
548. Where a closed (sealed) circulation system is used, the flow of the flushing agent and drilled cuttings emerging from the well shall be redirected to a special choke manifold to control the magnitude of the back pressure.
549. The discharge lines to the flares from the kill and choke units and/or the flow line shall be securely fastened on special supports and directed away from production and domestic structures with a slope away from the wellhead. The length of the lines shall be not less than 30 m.
550. The production casing is tested for tightness by pressure testing with industrial water to the design pressure provided for by the working design.
551. In the absence of high-pressure horizons in the section, pressure testing of the rocks after drilling out the cement cup below the conductor shoe and checking the tightness of the cement sheath behind the casing are not carried out.
552. Where the expected excess pressure at the wellhead is less than 5 MPa, pressure testing of the near-wellhead part of the casing with industrial water is permitted.
553. For each hazardous production facility a list of gas-hazardous locations and work shall be developed and approved, which shall be revised and approved by the technical manager or a person authorised by him upon a change in the process or the modernisation of equipment, reconstruction, or technical re-equipment. The development of a combined list of gas-hazardous locations and work covering several hazardous production facilities is permitted.
554. In enclosed premises where the release of vapours, gases and dust into the air is possible, and also in cases of changes in the processes, constant monitoring of the air environment shall be carried out. Data on the state of the air environment shall be recorded at the workplace and transmitted to the control room simultaneously with the transmission of the main process parameters of the facility's operation.
555. Within the organisation, an employee (employees) shall be appointed from among the managers, responsible, among other things, for the functioning of the industrial safety management system.
556. Process equipment and pipelines shall meet the requirements of safety, strength, corrosion resistance and reliability, taking into account the operating conditions.
557. A separate process facility of the main production shall have a control panel for monitoring and controlling the process.
558. The means of emergency alarm, fire monitoring and air-environment monitoring, installed in accordance with the design documentation, shall be in good working order, and their operability shall be checked in accordance with the manufacturer's operating manual on the schedule approved within the organisation.
559. On the discharge line of a piston pump, before the shut-off device, a check valve and a safety valve shall be installed, and on the discharge line of a centrifugal pump - a check valve.
560. On the control panel of a pumping station for pumping combustible, highly flammable and harmful liquids, instruments shall be installed enabling the monitoring of the pressure, flow rate, temperature of the bearings of the pump units and the state of the air environment in the premises.
561. Mobile pump units intended for work on wells shall be provided with shut-off and safety devices and have instruments monitoring the main process parameters, brought out to the control panel.
562. The operation of measuring instruments and automation systems shall be carried out in accordance with the operating instructions and the applicable regulatory and technical documentation.
563. The inspection of measuring instruments, technical systems and devices with a measuring function, automation equipment, and also interlock and signalling systems, shall be carried out on schedules approved by the technical manager of the organisation.
564. The installation and use of measuring instruments and measuring devices not conforming to the requirements of Federal Law No. 102-FZ of 26 June 2008 "On Ensuring the Uniformity of Measurements" (Collection of Legislation of the Russian Federation, 2008, No. 26, Article 3021; 2021, No. 24, Article 4188) shall not be permitted.
565. Pressure gauges shall be selected with a scale such that the measuring limit of the working pressure lies within the second third of the scale. A red line shall be marked on the dial of the pressure gauges, or a red plate shall be fixed on the body of the pressure gauge, adjoining the glass of the pressure gauge at the scale division corresponding to the maximum permitted working pressure. A pressure gauge installed at a height of from 2 to 3 m above the level of the platform for observing it shall have a diameter of not less than 160 mm.
566. The instrument air supplied to the automation system shall be cleaned and dried beforehand.
567. The compressed-air system shall have a working and a standby receiver. Each receiver shall provide a reserve of compressed air for the operation of all measuring instruments, regulating devices and automation equipment for a period of not less than one hour.
568. All measuring instruments, control boards, and the protective metal hoses of the incoming cable lines shall be earthed regardless of the voltage applied. All polymer pipelines or metal pipelines with a polymer coating shall be protected against the generation of static electricity.
569. All measuring instruments shall have markings indicating the measured parameters.
570. All activities for the thermal insulation of production premises, apparatus, technical devices, pipelines, fittings and measuring instruments shall be completed before the onset of the heating season.
571. Enterprises shall develop activities for preparing the hazardous production facility for operation during the winter period. The activities for preparation for winter shall ensure the normal operation of the hazardous production facility and ensure the possibility of monitoring the process during the winter period.
572. During the operation of installations, tank farms and loading-and-unloading racks, measures shall be taken to prevent the freezing of moisture in the pipelines and fittings. The putting into operation of apparatus and process pipelines with frozen drainage devices shall not be permitted.
573. On the pipelines, the thermal insulation shall be checked, all identified cases of damage to it eliminated, and the drainage pipelines and valves thermally insulated.
574. All water risers shall be thermally insulated.
575. The air heaters of the ventilation systems and the heating of all premises shall be checked in good time and be in good working order.
576. During the operation of oil-treatment installations handling oil with a high content of paraffins, resins and asphaltenes, activities shall be provided for: the repair of the thermal insulation of pipelines; the prevention of a decrease in the temperature of the oil in the pipelines and apparatus; the constant heating of the pipelines; the continuous pumping of the oil.
577. Upon completion of pumping, process pipelines carrying high-viscosity or paraffinic oil shall be flushed by pumping through a low-viscosity, non-congealing petroleum product.
578. When moisture freezes in a process pipeline, measures shall be taken for: the external inspection of the section of the pipeline to make sure that the pipeline is not damaged; the disconnection of the pipeline from the common system. If it is impossible to disconnect the pipeline and there is a threat of an accident, the installation shall be stopped and measures taken to heat up the ice plug.
579. The heating-up of the ice plug in the pipeline shall be carried out with steam or hot water, starting from the end of the frozen section.
580. The thawing of frozen drains (drainage points) of pipelines and apparatus with the gate valve open, and also with an open flame, shall be prohibited.
581. The use of hooks, crowbars and pipes to open frozen gate valves, valves and other shut-off devices shall not be permitted.
582. From disconnected apparatus, vessels, water lines and steam lines, the water and condensate shall be drained, and the drainage cocks (gate valves) left open.
583. The pressure testing of the Christmas tree in the assembled state before installation on the wellhead shall be carried out to the working pressure specified in the data sheet, with a hold under internal pressure of 30 minutes, and after installation on the wellhead - to the pressure-testing pressure of the production casing. The results of the pressure testing are documented by an act of a commission, which includes a representative of the operating organisation.
584. After the replacement of units and gate valves of the Christmas tree installed on the wellhead, the pressure testing is carried out with well pressure, but not higher than the pressure-testing pressure of the production casing, with the drawing up of an act.
585. The Christmas tree shall be equipped by the manufacturer with chokes with manual control and, at the customer's request, with remote control, with shut-off fittings with remote and/or manual control, and shall provide the possibility of replacing pressure gauges using a three-way cock or a valve with a bleed device without reducing the pressure to atmospheric.
586. Flowing wells with a flow rate of 400 t/day of oil or 500 thousand m3/day of gas and more, located at a distance of less than 500 m from a populated locality, and also offshore flowing wells with a flow rate of 400 t/day of oil or 500 thousand m3/day of gas, are equipped with downhole equipment (a packer and a cut-off valve, a circulation valve, a control station).
587. During the operation of the well, the downhole cut-off valve shall be periodically checked for actuation in accordance with the manufacturer's instructions. The installation of the cut-off valve and the checking of its actuation shall be documented by an act of the operating organisation.
588. On the well cluster pad, the gas-lift gas pipelines, pumpjacks, control stations, transformer substations, and cable racks shall be located on one side of the axis of the well cluster. The entry of transport (other than process transport) onto the territory of the well cluster shall be prohibited. The underground laying of the KETsN and SKN cable lines on the other side of the axis of the well cluster shall be justified by design decisions.
589. The arrangement of shaft pits (cellars) at the wellhead shall conform to the working design for the drilling of wells, taking into account the specific dimensions of the casing heads, the blowout prevention equipment and the conditions of the given region, depending on the category of the well.
590. On the flow lines and manifolds of wells operating with a working-medium temperature of 80 °C and more, temperature compensators shall be installed.
591. The elimination of faults and the replacement of rapidly wearing and replaceable parts of the Christmas tree under pressure shall be prohibited. In individual cases, in emergency situations, this work may be carried out by workers of regular or non-regular emergency rescue units.
592. After the installation of the manifold and its connection to the outlets of the Christmas tree and the tubing head, a hydraulic test of the system to the working pressure is carried out.
593. The control station of the Christmas tree of a gas-lift well shall be installed at a distance of 30 - 35 m from the wellhead in a special room, securely fastened and earthed. The temperature in the room shall ensure the failure-free operation of the station.
594. The air lines and cables connecting the control station to the Christmas tree shall be laid on racks.
595. The conversion of a well to gas-lift operation shall be carried out in accordance with a plan approved by the technical manager of the organisation.
596. Before converting a well to gas-lift operation, the production casing, the wellhead equipment and the tubing shall be pressure-tested to the maximum (start-up) pressure.
597. For the piping of the well, seamless steel pipes joined by welding shall be used. Flanged connections are permitted only at the locations where gate valves and other fittings are installed.
598. During the installation and operation of the pipelines of the wellhead piping, the following requirements shall be ensured: the pipelines shall be laid tightly, without gaps or skewing, on the cushions of the fixed supports; the fastening of the pipes with clamps shall exclude the possibility of their displacement; the upper planes of the supports shall be levelled, if this requirement is provided for by the documentation; the bearing surfaces shall be in contact over the entire contact area without skewing; the installation of shims between the pipe and the support cushion to provide the required slope of the pipeline shall be prohibited; when laying the pipelines, the welded seams shall be located at a distance of not less than 50 mm from the edge of the support for pipes with a diameter of less than 50 mm and not less than 200 mm for pipes with a diameter of more than 50 mm.
599. After installation, the gas-distribution pipelines shall be purged with compressed air and pressure-tested with liquid to a pressure exceeding the maximum working pressure by 25 per cent. The gas-distribution devices shall have systems for the individual automatic measurement of the gas flow rate with the control system brought out to the control room, vent stacks for purging and devices for the supply of inhibitor.
600. The wellhead of a gas-lift well shall be equipped with a Christmas tree with a manifold having purge lines with an outlet to a vent stack located not less than 20 m away. A check valve is installed on the manifold.
601. The preparation of the working agent (gas) during gas-lift operation shall provide for its drying from water vapour to a dew point of -10 °C for southern regions and -20 °C for the middle and northern latitudes.
602. When eliminating hydrate plugs, the pressure in the gas pipeline shall be reduced to atmospheric, and the heating of these sections carried out with steam. If the throughput capacity is retained, the preliminary supply of inhibitor without stopping the gas pipeline is permitted.
603. During the operation of the compressor station of the gas-lift system, the following shall be carried out: a shift-by-shift inspection of all on-site process pipelines, separators, vessels, and shut-off and control fittings, with the recording of the results in accordance with the work procedures of the operating organisation; monitoring of the operability of the gas-drying, lighting, ventilation and emergency alarm systems, lightning protection, protection against static electricity, communications and telemechanisation on the approved schedule.
604. The wellhead is equipped with shut-off fittings and a stuffing-box device for sealing the rod.
605. The wellhead piping shall allow the replacement of the stuffing-box packing of the polished rod when there is pressure in the well, the measurement of the wellhead pressure and, if necessary, of the temperature.
606. In the suspension of the wellhead rod, the rope shall extend beyond the lower crosshead by a length that does not permit contact with the elements of the wellhead fittings.
607. Before the start of repair work, when stopping for a long period, or before the inspection of the equipment of a periodically operating well with automatic, remote or manual start-up, the electric motor shall be switched off; measures shall be taken to prevent its accidental setting in motion as a result of the erroneous or spontaneous switching-on of the switching devices; the counterweight shall be lowered to the bottom position and locked by the braking device; and a sign "Do not switch on! People at work" shall be hung on the button of the start-up device.
608. On wells with automatic and remote control of the pumpjacks, near the start-up device, in a prominent place, there shall be a sign: "Attention! Automatic start-up".
609. The crank-and-connecting-rod mechanism of the pumpjack, and the platform for servicing the electric drive and the start-up device, shall be painted and have guards.
610. The flow-rate measurement systems and the systems for monitoring the start-up and shutdown of the well shall have an output to the control room.
611. The pumpjack shall be installed so as to exclude contact of the moving parts with the foundation or the ground.
612. For servicing the brake of the pumpjack, a platform with a guard is provided.
613. In the extreme lower position of the walking-beam head, the distance between the crosshead of the suspension of the stuffing-box rod or the rod holder and the wellhead stuffing box shall be not less than 20 cm.
614. The conductor (intermediate casing) shall be connected to the frame of the pumpjack by not less than two earthing steel conductors welded at different points to the conductor (the technical casing) and the frame. Where a sub-frame is present, the frame of the pumpjack and the sub-frame shall be connected to each other by not less than two round steel conductors with a diameter of not less than 10 mm, welded at different points of the sub-frame and the frame, provided that the sub-frame and the pile field are connected by welding. The cross-section of a rectangular conductor shall be not less than 48 mm2, the wall thickness of the angle steel not less than 4 mm, and the diameter of the round earthing electrodes not less than 10 mm. The earthing conductors connecting the frame of the pumpjack to the conductor (the technical casing) shall be buried in the ground to a depth of not less than 0.5 m. Steel may be used as earthing conductors: round, strip, angle or of another profile. The use of steel rope for these purposes shall be prohibited. The connections of the earthing conductors shall be accessible for inspection.
615. Wells operated with the use of submersible pumps may be equipped with bottomhole cut-off valves that allow the replacement of downhole equipment and process operations to be carried out without killing the well.
616. In the absence of a cut-off valve or in the event of its failure, the well shall, before repair, be killed with a process fluid that does not contain solid suspended matter and does not impair the filtration properties of the bottomhole zone.
617. The parameters of the process killing fluid are specified in the plans for carrying out repair work.
618. The wellhead is equipped with a Christmas tree or a special wellhead device ensuring the sealing of the tubing and annular spaces, the possibility of their communication and of carrying out downhole surveys. The piping of the flow lines of the tubing and annular spaces shall allow the bleeding-off of the well, the supply of gas, process fluids and chemical reagents into the annular space, and the performance of process operations, including the killing of the well. The through-hole for the power cable in the wellhead fittings shall have a sealed packing.
619. The power cable shall be laid from the control station or from the nearest terminal box to the wellhead on a rack. The laying of the cable on special support posts is permitted. The power cable shall not touch the Christmas tree and the well piping. The earthing of the armour of the power cable is carried out to the conductor of the well or to the bolted connection of the lower flange of the casing head.
620. Cables (including armoured ones) located in places where mechanical damage is possible (the movement of motor vehicles, machinery and loads, accessibility to unauthorised persons) shall be protected to a height of 2 m above the level of the floor or the ground and to 0.3 m in the ground.
621. The cable roller shall be suspended on the mast of the hoisting unit by means of a chain or on a special rope suspension and secured with a cable of a diameter of not less than 8 mm.
622. The cable passed through the roller shall not, during hoisting-and-lowering operations, touch the structural elements of the lifting mechanisms or the ground.
623. When making up and breaking out pipes, the cable shall be moved aside beyond the limits of the working zone in such a way that it does not hinder the workers.
624. The speed of lowering (raising) the submersible equipment into the well shall not exceed 0.25 m/s in directional and horizontal wells with a build-up of curvature of more than 1.5 degrees per 10 m; the lowering speed shall not exceed 0.1 m/s in the curvature intervals.
625. The production casing of a well into which a submersible electric pump is being run for the first time, and also when the pump size is increased, shall be checked with a drift in accordance with the requirements of the operating manual of the submersible electric pump.
626. The room of the process block of the installation shall have: constant forced ventilation ensuring an eight-fold air exchange of the full internal volume of the room within an hour; a temperature in the blocks of not lower than 5 °C, a noise level of not more than 85 dB, a vibration velocity of not more than 2 mm/s.
627. Before entering the room of the process block, the following shall be done: check the gas contamination of the room and the state of the ventilation system; switch on the lighting.
628. Before running the packer, the production casing shall be drifted, if necessary reamed, washed to the bottomhole and pressure-tested.
629. The removal of the hydraulic piston pump, the scraper and other equipment shall be carried out with the use of a special lubricator included in the set of the installation.
630. The installation and dismantling of the lubricator shall be carried out with the use of the mast, with the central gate valve closed, in compliance with the instructions for work of this type.
631. Each discharge line shall be equipped with a pressure gauge and a flow-rate regulator for the working fluid.
632. Power pumps shall be equipped with electrical-contact indicating pressure gauges, and also with safety valves. The outlet from the safety valve of the power pump shall be connected to the pump intake.
633. The serviceability of the automation system and the safety devices is checked within the periods established by the operating instructions.
634. The power unit is started up after checking the serviceability of the automation system, with the shut-off devices open on the suction, discharge and bypass lines of the working fluid of the power pump. The pressure in the pressure system is created after the normal operating mode of the surface equipment is established.
635. When the power pump is stopped, the pressure in the discharge pipeline shall be reduced to atmospheric.
636. The system for measuring the flow rate of the wells and the operating readings of the power pumps shall have an output to the control room
637. The wellhead equipment of an injection well shall conform to the working design for the drilling of the well, in the development of which the composition and physico-chemical properties of the injected agent and the maximum expected injection pressure shall be taken into account.
638. Injection wells, regardless of the physico-chemical properties of the injected agent, shall be equipped with a tubing string and a packing device ensuring the protection and isolation of the production casing from the effect of the injected agent on it. On the discharge line of a water-injection well for reservoir-pressure maintenance, a check valve shall be installed, located on the territory of the well cluster pad or the pad of a single well.
639. To prevent the freezing of water in the well fittings and the injection system during stoppages, the complete removal of water from the fittings and the supply system of the working agent shall be provided for.
640. The design documentation shall provide for sites for the placement of well-survey installations, and also decisions on their power supply and earthing.
641. The frequency and scope of surveys of production wells are established on the basis of approved work plans developed in accordance with the design documentation for the development of the given field.
642. The lowering of downhole instruments and tools run on a rope shall be carried out only with a lubricator with a sealing stuffing-box device installed on the wellhead.
643. Hoisting-and-lowering operations shall be carried out with the use of a winch ensuring the rotation of the drum with the rope in any desired speed ranges and with a fixed load on the rope (wire). The use of hoists with a mechanical drive is permitted where the load on the rope is controlled.
644. Before installation on the well, the lubricator is subjected to a hydraulic test to the pressure expected at the wellhead. After installation and before each operation, the lubricator shall be checked for tightness by gradually increasing the pressure of the well production.
645. The wire used for downhole surveys shall be solid, without twists, and for work with a hydrogen sulphide content of more than 6 per cent - made of a material resistant to hydrogen sulphide corrosion, and, when raised, the wire shall pass through a sealed device with a hydrogen sulphide neutraliser.
646. The surveying of exploratory and production wells in the absence of the possibility of disposing of the liquid product shall not be permitted.
647. Work on the injection of gas, steam, chemical and other agents into the well is carried out in accordance with a work plan approved by the technical manager of the organisation carrying out such work and agreed with the organisation operating the hazardous production facility (the customer). The plan shall specify the procedure for the preparatory work, the layout of the equipment, the technology of the process, the safety measures, and the responsible person in charge of the work.
648. Before carrying out work on enhancing the oil and gas recovery of the reservoirs, pressure testing of the production casing to the pressure established by the work plan shall be carried out. The casing is considered tight if, within 30 minutes, the pressure-testing pressure has decreased by not more than 0.5 MPa. The presence of a representative of the customer at the pressure testing is mandatory. The results of the pressure testing are documented by an act. During the work, monitoring of the pressure in the annular and inter-casing spaces shall be carried out.
649. In the case of work (hydraulic fracturing of the formation, acid treatments, various fillings, etc.) requiring pressures exceeding the pressure-testing pressures of the casing string, special fittings shall be installed on the wellhead, and the production casing shall be protected by the installation of a packer.
650. When injecting gas, steam, chemical and other agents, a check valve shall be installed on the discharge line at the wellhead.
651. The injection system, after assembly and before the start of injection, shall be pressure-tested to one-and-a-half times the expected working pressure.
652. During hydraulic tests of the injection systems, workers shall be removed beyond the limits of the danger zone established by the work plan. The elimination of leaks under pressure in the system shall be prohibited.
653. Before the start of the process at the well with the use of mobile units, the person in charge of the work shall make sure of the availability of two-way voice communication.
654. Before the start of work on the injection of gas, steam, chemical and other agents, and after a temporary stoppage in winter time, the absence of ice plugs in the communications of the pump units and in the discharge lines shall be verified. The heating of pipelines with an open flame shall be prohibited.
655. The treatment of the bottomhole zone and the stimulation of inflow in wells with non-tight casing and behind-casing crossflows shall not be permitted.
656. For the period of thermal and complex treatment, a danger zone with a radius of not less than 50 m shall be established around the well and the equipment used.
657. Mobile pump units shall be located at a distance of not less than 10 m from the wellhead; the distance between them shall be not less than 1 m. Other installations for carrying out the work (a compressor, a steam-generator installation) shall be placed at a distance of not less than 25 m from the wellhead. The units are positioned with their cabs facing away from the wellhead.
658. The process modes of carrying out the work and the design configuration of the units and installations shall exclude the possibility of the formation of explosive and fire-hazardous mixtures inside the apparatus and pipelines.
659. At all facilities (wells, pipelines, measuring installations), the formation of explosive mixtures shall not be permitted; the work plans shall provide for systematic monitoring of the gas-air environment during the work.
660. The flow line from the safety device of the pump shall be rigidly fastened and led into a discharge vessel for collecting the liquid or to the pump intake.
661. Vibration and hydraulic shocks in the discharge communications shall not exceed the values established in the work plans.
662 Work shall be carried out using the necessary personal protective equipment and in accordance with the requirements of the instructions for the use of the reagents applied.
663. At the site where work on the injection of aggressive chemical reagents (sulphuric, hydrochloric and hydrofluoric acids) is carried out, there shall be: an emergency stock of special clothing, special footwear and other personal protective equipment; a stock of clean fresh water; neutralising components for a solution (chalk, lime, chloramine).
664. Residues of chemical reagents shall be collected and delivered to a specially designated place equipped for their disposal or destruction.
665. After the injection of chemical reagents or other harmful substances, before dismantling the injection system of the unit, an inert liquid shall be pumped through in a volume sufficient to flush the injection system. The discharge of the liquid after flushing shall be carried out into a collecting tank.
666. To determine the concentration of sulphuric acid vapours and sulphuric anhydride, the work team shall be provided with gas analysers.
667. Loading of the thermal reactor shall be carried out immediately before it is run into the well.
668. The loaded thermal reactor, the tanks and the work sites shall be located at a distance of not less than 10 m from the injection pipelines and tanks with acids.
669. Equipment and pipelines shall be protected against corrosion.
670. During the purging of the well or a section of the injection pipeline, being closer than 20 m to those sections shall not be permitted.
671. Constant monitoring of the air of the working area shall be carried out. If the content of carbon dioxide in the air of an enclosed space is above the maximum permissible concentration (0.5 per cent (by volume)) and the tightness of the carbon dioxide distribution and collection system is breached, work shall be stopped.
672. The in-situ combustion process shall be carried out in accordance with the work plan. The oil and gas collection system shall be closed and shall provide for the use of the gaseous products of the process. Where carbon dioxide is present in the production, its collection and separation are carried out through a separate system. The discharge of carbon dioxide into the atmosphere shall be prohibited.
673. During the period of combustion initiation, the wellhead of the injection well shall be equipped with a Christmas tree with a remotely controlled valve that prevents the possibility of a blowout and ensures the lowering and raising of the electric heater and the sealing of the wellhead during the period of air injection.
674. Around the injection well, during the period of initiation of in-situ combustion, a hazardous zone with a radius of not less than 25 m shall be established, marked with warning signs. The installation of various equipment, tanks and instrumentation panels within the hazardous zone shall be prohibited.
675. The switching on of the electric heater shall be carried out only after air has been supplied into the well in the volume provided for by the work plan.
676. The electric heater shall be equipped with a device that automatically switches it off when the air supply ceases.
677. Steam-generating and water-heating installations shall be equipped with instruments for monitoring and controlling the processes of preparation and injection of the heat-transfer medium, and with means for stopping the supply of fuel gas in cases of disruption of the process.
678. The laying of pipelines from stationary installations to the well for the injection of wet steam or hot water and their operation is carried out in compliance with the requirements for the safe operation of steam and hot-water pipelines established by Rostechnadzor.
679. The distance from the steam-distribution point or the distribution steam line to the wellhead of the injection well shall be not less than 25 m.
680. The control of the shut-off valves of a well equipped for the injection of steam or hot water shall be carried out remotely. Flanged joints shall be covered with casings.
681. In emergency cases, the operation of the steam-generating and water-heating installations shall be stopped, and the workers shall act in accordance with the PMLA.
682. On the fuel supply line to the furnace of the steam generator, automatic protection is provided that stops the fuel supply when the pressure in the heat pipeline changes below or above the permissible value, and also when the water supply ceases.
683. The territory of wells equipped for the injection of steam or hot water shall be fenced and marked with warning signs.
684. The injection of the heat-transfer medium into the formation shall be carried out after the installation of a heat-resistant packer at a pressure not exceeding the maximum permissible pressure for the production casing.
685. The outlet from the annular space shall be directed towards an area free of machinery and workers. During the injection of the heat-transfer medium (with the installation of a packer), the valve on the outlet from the annular space shall be open.
686. After treatment of the well, the connecting devices shall be checked, and the fittings shall be painted.
687. The installation for heating the petroleum product shall be located not closer than 25 m from the tank with the hot petroleum product.
688. The electrical equipment used at the installation for heating the petroleum product shall be of explosion-proof design.
689. The tank with the hot petroleum product shall be installed at a distance of not less than 10 m from the wellhead on the leeward side.
690. The work execution plan shall provide for measures ensuring the safety of the workers. Work shall be carried out in strict compliance with the instructions in force at the organisation.
691. Downhole electric heaters shall be of explosion-proof design. The assembly and testing of a downhole electric heater by connecting it to a current source shall be carried out in the electrical workshop. The disassembly and repair of downhole electric heaters and their testing under load in field conditions shall not be permitted.
692. The lowering of the downhole electric heater into the well and its raising shall be mechanised and carried out with a sealed wellhead using a special lubricator.
693. Before installing the support clamp on the cable-rope of the electric heater, the wellhead shall be closed.
694. The mains cable may be connected to the starting equipment of the electric heater only after the cable-rope has been connected to the transformer and the electrical equipment has been earthed, all preparatory work in the well and at the wellhead has been carried out, and people have been removed.
695. Powder charges (powder pressure generators or pressure accumulators) for the integrated treatment of the bottom-hole zone of the well shall be stored and transported in accordance with the safety requirements for blasting operations established by Rostechnadzor.
696. Powder pressure generators (accumulators) shall be installed in the charge string being lowered only before it is introduced into the lubricator.
697. Boxes with powder charges shall be stored in a room that is locked and located at a distance of not less than 50 m from the wellhead.
698. The string of powder charges is installed in the lubricator only when the central valve is closed. The device being lowered shall not touch the rams of the valves. The work shall be carried out by two workers.
699. The connection of a powder generator or pressure accumulator lowered to the bottom of the well to the control instruments and the electrical mains is carried out in the following order: sealing of the wellhead; connection of the electric cable of the charge string to the transformer (distribution board); removal of the members of the work team and other persons present on the work site (except the direct performers) to a safe distance from the wellhead - not less than 50 m; setting the code of the connection instruments to the "off" position; connection of the mains cable to the transformer or the control instruments; taking measures to prevent the induction of stray currents; supply of electric power to the control instruments; switching on of electric power to the charge string (carried out only on the command of the responsible person in charge of the work).
700. When powder charges or other elements of hydraulic fracturing of the formation are used during the combined treatment of the bottom-hole zone of the well, the requirements ensuring the integrity of the production casing are met.
701. Hydraulic fracturing of the formation is carried out under the supervision of a responsible engineering and technical worker according to a work plan approved by the technical manager of the organisation.
702. During the hydraulic fracturing of the formation, the presence of workers near the wellhead and at the injection pipelines shall be prohibited.
703. The pressure header of the manifold block shall be equipped with instrumentation sensors, safety valves and a liquid discharge line, and the injection pipelines - with check valves.
704. After the wellhead has been tied in, the injection pipelines shall be pressure-tested to the pressure expected during hydraulic fracturing of the formation with a safety factor of not less than 1.25.
705. When carrying out hydraulic acid fracturing, corrosion inhibitors shall be applied.
706. The injection pipelines of heat-generating installations shall be: equipped with a safety valve and a check valve; pressure-tested, before work in the well is carried out, to one and a half times the expected maximum pressure, but not exceeding the pressure specified in the data sheet of the installations.
707. Mobile de-paraffinisation installations may be installed at a distance of not less than 25 m from the wellhead and 10 m from other equipment.
708. During the steaming of the flowline, approaching it and the wellhead to a distance of less than 10 m shall be prohibited.
709. The ignition of the steam boiler and the oil heater shall be carried out in accordance with the operating instructions of the manufacturer.
710. The use of rubber hoses for the supply of the heat-transfer medium under pressure shall not be permitted.
711. The processes of production, collection and treatment of oil and gas, their technical equipment, the choice of control and regulation systems, the locations of monitoring, control and emergency-protection devices shall be taken into account in the design documentation for the development and shall ensure the safety of the operating workers and the population. During the operation of a hazardous production facility, existing automation devices and measuring instruments having technical and metrological parameters more advanced than those specified in the design documentation may be replaced.
712. Enclosed spaces of the facilities for the collection, treatment and transportation of oil, gas and condensate (UPNG, UPPN, UKPG, UPPG, DKS, NPS, DNS, KNS, PSP, KSP), where the formation of harmful, combustible substances or toxic gases in the air of the working area is possible, shall have a system for monitoring the state of the air environment and emergency ventilation, interlocked with a system of audible and visual emergency alarms. The actions of workers when emergency signals arise shall be defined in the PMLA. All enclosed spaces shall have a permanently operating supply-and-exhaust ventilation system with natural or mechanical induction. The intensity of air exchange is determined by the design documentation. The main process parameters of these facilities and data on the state of the air environment shall be output to the control point (dispatch point).
713. Control systems shall have signalling devices to warn of the shutdown of facilities and two-way communication with the dispatch point.
714. Each facility (technical device) controlled from the dispatch point shall also have manual control directly at the facility.
715. The oil and gas collection system shall be closed (except for mine-method oil production), and the wellheads of injection, observation and production wells shall be sealed.
716. At the facilities for the collection and treatment of oil, at pumping and compressor stations, a process flow diagram approved by the technical manager of the organisation shall be posted, indicating the numbers of the valves, apparatus and flow directions, fully corresponding to their numbering in the design documentation. The process flow diagram shall be posted in the operator rooms, machine halls and other premises in places accessible to workers.
717. Changes to the process, the diagram, the regulations and the equipment configuration may be introduced only where there is regulatory-technical and (or) design documentation agreed with the organisation that developed the process and (or) the organisation that developed the documentation being changed.
718. The reconstruction and replacement of elements of the process flow diagram without approved design documentation shall not be permitted.
719. Equipment that has been in contact with sour oil and is not used in the current process flow diagram shall be disconnected, freed of product, washed (steamed), filled with an inert medium and isolated from the equipment involved in the process by the installation of blanks. The installation of blanks is recorded in the log of installation and removal of blanks.
720. Where hydrogen sulphide is present in the production, in process apparatus, reservoirs and other tanks, or where there is a possibility of the formation of harmful substances during explosions, breaches of the tightness of tanks and other emergency situations, workers shall be provided with the necessary personal protective equipment against the effect of these substances.
721. The rate of change of process parameters shall be established by the process regulations and the manufacturer's operating instructions for the equipment.
722. In the case of the detection of gas contamination of the air of the working area, the workers of nearby installations shall be immediately warned of the possible danger, the gas-contaminated area shall be cordoned off, and measures shall be taken to eliminate the source of the gas contamination.
723. In the case of a malfunction of the instruments for determining explosive concentrations, immediate measures shall be taken to restore their operability, and for the duration of the repair work to restore their operability, actions ensuring the safe operation of the installation shall be carried out.
724. The operation of apparatus, vessels and other equipment operating under pressure shall not be permitted with faulty safety valves, disconnecting and regulating devices, or in the absence or malfunction of the measuring instruments of the automation.
725. The draining of water from apparatus and tanks shall be carried out manually or automatically into a closed system (tank).
726. The electrical equipment of the installation shall be serviced by workers who have the appropriate qualification and admission to work.
727. The operation of compressors and pumps shall be prohibited in the absence or faulty condition of the automation and monitoring devices and the interlock system specified in the data sheet and the manufacturer's operating instructions.
728. On the pipelines there shall be arrows indicating the direction of movement of the working medium through them.
729. Oil for the lubrication of the compressor and the pump may be used only where there is manufacturer's documentation for it (a data sheet, a certificate).
730. Equipment for the collection of oil, gas and condensate shall meet the requirements of the standards and technical specifications for their manufacture, shall be installed in accordance with the design documentation and the process design norms in force, and shall ensure complete tightness and preservation of the production (a closed system for the collection and treatment of oil and gas).
731. Equipment shall be fitted with monitoring instruments (with the output of readings to the control panel), regulating and safety devices.
732. Units with rotating elements undergo vibration-diagnostic monitoring upon commissioning from installation, before being taken out for repair and after a major overhaul, and also during operation in accordance with a schedule approved by the operating organisation.
733. The serviceability of the safety, regulating and shut-off valves installed on apparatus and pipelines shall be subject to periodic checking in accordance with a schedule approved by the operating organisation. The results of the checks are recorded in the shift log or are documented by other documents established by the operating organisation.
734. Vessels and apparatus operating under pressure are equipped with pressure gauges, liquid level indicators, shut-off and safety fittings, devices for internal inspection, and also a drainage line for the removal of liquid, the necessity of which is determined by the operating documentation of the manufacturer or the developer of the technical device.
735. Electrical sensors of the process monitoring and control systems shall be of explosion-proof design and shall be rated for use under conditions of vibration, the formation of gas hydrates, deposits of paraffin, salts and other substances.
736. Process pipelines and pipeline fittings (shut-off, shut-off-and-regulating, regulating, safety) are provided with warning signs and inscriptions, indicators of the direction of flow of gas, air and other products.
737. Standby pumps shall be kept in constant readiness for starting. Pumps that pump sour oil shall be filled with the pumped liquid to avoid the formation of pyrophoric deposits.
738. The detachable joints of compressors and their gas pipelines shall be systematically checked for tightness in accordance with the periods established by the operating instructions of the manufacturer.
739. Leaving operating compressors, except for fully automated ones, without the supervision of the persons servicing them shall not be permitted.
740. Gas-compressor stations shall be equipped with: instruments for monitoring the process parameters (pressure, flow rate, temperature) of the transported product; a system of instruments for the diagnostics of the compressor equipment (vibration, bearing temperature); a system for monitoring the air environment in the premises of the compressor station; a ventilation system; a system of warning signalling of the disruption of process parameters and gas contamination of the air environment in the compressor room; a system for stopping and interlocking the starting of compressors when the gas contamination of the air environment in the compressor room exceeds 40 per cent of the lower concentration limit of flame propagation on one sensor or 20 per cent on two or more sensors, or on a malfunction of the ventilation system; control panels in the compressor room and in the operator hall; an explosion-safe communication system; fire-protection systems.
741. The conduct of the oil treatment process shall be carried out in accordance with the process regulations.
742. The checking of the serviceability, before the starting of the UPN complex, of the technical devices, pipelines, fittings, metal structures, earthing devices, measuring instruments and automation, interlocks, ventilation and communication that are part of it, of the availability of personal protective equipment and other systems is carried out according to a plan approved by the technical manager of the organisation.
743. The electrical part of the installation shall be serviced by workers who have admission to carry out work on electrical installations with a voltage above 1000 V.
744. On the body of each electric dehydrator, near the ladder, its number shall be marked, which is also indicated on the corresponding panel of the control board of the electric dehydrator (on the front and back sides).
745. The upper platform on which the transformers and reactive coils are located shall have a mesh or lattice enclosure with warning posters "Stop, voltage" hung on it.
746. The enclosure of the electric dehydrator platform shall have an interlock that removes the voltage when the door of the enclosure is opened.
747. Entering beyond the enclosure during the operation of the electric dehydrator shall be prohibited.
748. The electric dehydrator shall have a device that switches off the voltage when the level of the product in the apparatus decreases. The checking of all the interlocks of the dehydrator shall be carried out according to a schedule approved by the operating organisation, but not less than once a year.
749. After the electric dehydrator has been filled with product, before the voltage is supplied, the gases and vapours accumulated in it shall be removed.
750. The voltage shall be supplied to the installation by the worker on duty on the instruction of the head of the installation or the person replacing him.
751. In the event of fire on the electric dehydrator, the voltage shall be immediately removed.
752. The draining of water from electric dehydrators and settling tanks shall be automated and carried out into a closed drainage system.
753. For a UPN, oil-heating furnaces shall be chosen that are fully automated, with programmed start-up (except for furnaces with panel burners) and emergency shutdown when the process parameters deviate by the established value.
754. Equipment with fire heating shall be equipped with technical means that exclude the possibility of the formation of explosive mixtures in the combustion space and the working area of the furnace.
755. The operation of heating furnaces shall not be permitted in the absence or malfunction of: systems for regulating the set ratio of fuel, air and water vapour; interlocks that stop the supply of gaseous fuel and air when their pressure decreases below the established parameters, and also when the electrical and pneumatic supply of the instrumentation and automation instruments ceases; means of signalling the cessation of the supply of fuel and air during their forced supply into the combustion space; means for monitoring the draught level and for the automatic stopping of the supply of fuel gas into the combustion zone when the smoke exhauster stops or when the vacuum in the furnace decreases impermissibly, and, where furnace units are configured with waste-heat boilers, systems for switching the units to operation without smoke exhausters; a system for freeing the coils of the furnace from the heated liquid product in the event of damage to the tubes or the cessation of its circulation; means for the remote disconnection of the supply of feedstock and fuel in the event of accidents in the coil systems.
756. The ignition of panel burners shall be carried out at a gas pressure in the headers corresponding to the norms set by the process regulations.
757. The ignition of a block of panel burners shall be carried out by not less than two workers.
758. During the operation of the furnace, the temperature of the outer walls of the distribution chambers of the burners shall be monitored, and, in the event of a dangerous increase of it (more than 60 °C), the burner shall be switched off.
759. When "pops" appear, the burner shall be switched off and the nozzle cleaned.
760. During the operation of a furnace with injectors, periodic visual monitoring of the condition of the coil tubes, the tube hangers and the furnace lining shall be ensured.
761. The operation of a furnace with injectors shall not be permitted where there is deformation of the tubes, deformation of the lining or hangers, or other visible malfunctions.
762. In the event of burn-through of the tubes of a furnace with injectors, its operation shall be stopped in accordance with the emergency shutdown mode.
763. On the steam line or the inert-gas pipeline serving to purge the coil of a furnace with injectors during stoppages or an accident, check valves and two shut-off gate valves each shall be installed. Between the gate valves, a test (purge) cock shall be provided for monitoring the tightness of the gate valve and for draining the condensate.
764. The valves of the pipelines of the steam-extinguishing system of the combustion chamber of a furnace with injectors and of the return-bend box shall be located in a place convenient for approach and safe, at a distance of not less than 10 m from the furnace.
765. The pipelines supplying gas to non-operating injectors shall be blanked off.
766. UKPG (group and gas-collection points) shall ensure the complete and effective use of the resources of natural and petroleum gas.
767. For UKPG, gas-collection points, head structures and other facilities, process regulations shall be developed and approved by the head of the operating organisation.
768. The gas pipelines of UKPG, gas-collection points, head structures and other facilities shall meet the requirements for first-category pipelines (at a design pressure of more than 2.5 MPa but not more than 10 MPa).
769. On each steam line, at the entry into the apparatus, a check valve and a disconnecting device rated for the working pressure in the apparatus shall be installed.
770. UKPG shall have systems for the cleaning, drying, heating and inhibition of gas. Hydrate plugs in the gas pipeline, fittings, equipment and instruments shall be eliminated by the introduction of hydrate-formation inhibitors, heat-transfer media (steam, hot water), and by lowering the pressure in the system. The use of open fire for heating the equipment shall be prohibited.
771. Tightening (carrying out adjustment) and plugging safety valves, if a leak is detected in them, shall be prohibited. In these cases, the operation of the apparatus, equipment and pipelines shall be stopped and the valve shall be replaced.
772. The process regulations of the installation specify the list of process parameters and their limit values. When the parameters deviate from the limit values, the installation shall be stopped.
773. Before the starting of the installation, the serviceability of the equipment, pipelines, fittings, metal structures, earthing devices, instrumentation and automation, interlocks, ventilation and sewerage, and personal protective equipment shall be checked, and the air shall be displaced from the system with inert gas to the vent stack. At the end of the purging, an analysis of the outgoing gas is carried out. The oxygen content shall not exceed 1 per cent by volume. The displacement of air from apparatus and tanks into the common flare system shall be prohibited.
774. The starting of the installation shall not be permitted with faulty systems for monitoring the hazardous parameters of the process and with faulty protection systems.
775. The sampling of gas, condensate and other process media shall be carried out with the aid of samplers rated for the maximum pressure in the equipment. The use of samplers with faulty needle valves and with an overdue period of their checking shall be prohibited. The checking of the valves for tightness is carried out not less than once every 6 months.
776. Work on the adjustment, repair and testing of equipment, of monitoring systems, of the control of the emergency automatic protection of equipment, pipelines, communication and warning shall exclude spark formation. For carrying out such work in explosion-hazardous zones, a permit to work is issued, and measures ensuring the safety of the organising and conducting of the work are developed.
777. The warning and emergency alarms shall be permanently switched on in operation.
778. Shift workers may carry out only emergency disconnections of individual instruments and automation devices in the order established by the production instructions.
779. For pumps (a group of pumps) that pump combustible products, their remote disconnection and the installation of shut-off or cut-off devices on the inlet and discharge lines shall be provided for.
780. Pumps used for the injection of liquefied combustible gases, flammable liquids, shall be equipped with: interlocks that prevent the starting or stop the operation of the pump in the absence of the moved liquid in its casing or when its levels in the supply tanks deviate from the maximum permissible values; means of warning signalling of the disruption of the operating parameters affecting the safety of operation.
781. For the pumping of flammable liquids and liquefied hydrocarbon gases, sealless pumps with a double mechanical seal, and, in justified cases, with a single mechanical additional seal, shall be used. The type of mechanical seal is chosen depending on the zone of installation and the properties of the pumped product.
782. The pump supplying oil to the mechanical seals shall be provided with an interlocking device that starts the standby oil pump upon a drop in oil pressure.
783. A check valve shall be installed on the pressure (discharge) pipeline of a centrifugal pump, and a filter shall be installed on the suction pipeline. Starting and stopping a centrifugal pump with the gate valve on the pressure (discharge) pipeline open shall not be permitted.
784. The casings of pumps handling flammable and combustible products shall be earthed independently of the earthing of the electric motors located on the same frame as the pumps.
785. All pumps shall be equipped with drainage devices that discharge the drained product into a closed recovery system.
786. When pumps are emptied and purged, the discharged product shall be conveyed outside the premises: the liquid - through pipelines into a specially designated vessel, and the vapours and gases - to the flare or the vent stack.
787. The arrangement of pipelines in pumping stations shall ensure ease of their servicing. The trays shall be covered with ribbed metal decking. The decking shall have recessed handles for lifting.
788. The pipelines located in pumping stations shall be marked with their purpose and the direction of product flow, the pumps - with indices in accordance with the process flow diagram, and the motors - with the direction of rotor rotation.
789. During the operation of pumps, monitoring of the discharge pressure shall be ensured. The operation of a pump with faulty pressure gauges or with pressure gauges that have not undergone timely verification shall be prohibited.
790. Lubrication of moving parts and the elimination of leaks in glands, mechanical seals and pipeline connections while the pump is running shall not be permitted.
791. If any fault is detected that disrupts the normal operating mode of the pump, the latter shall be stopped, checked, and the fault eliminated. Repairing the pump while it is running shall be prohibited.
792. The standby pump shall at all times be kept in constant readiness for starting; only gate valves shall be used to disconnect it from the suction and pressure manifolds. The use of blanks for that purpose shall be prohibited.
793. When the pump is stopped, the supply of water used for cooling the pump glands shall be shut off.
794. Starting steam pumps without first draining the steam condensate and warming up the steam cylinders shall be prohibited. In doing so, the gate valve on the pump discharge pipeline shall be open. Placing rags or any other objects on the hot parts of the pump and pipelines shall not be permitted.
795. Where it is necessary to move the piston of a steam pump from the dead position by hand, the gate valves on the suction and discharge product pipelines, as well as the steam valves on the steam lines of the incoming and exhaust steam, shall be closed, and the pressure bled off.
796. Compressors shall be equipped with serviceable shut-off valves, measuring instruments, protection systems and interlocks in accordance with the manufacturer's data sheet and the requirements of the design documentation, taking into account the properties of the products conveyed.
797. Compressors shall be operated in accordance with the manufacturer's operating instructions.
798. Using compressors to compress gas that does not correspond to their data-sheet parameters shall not be permitted.
799. Where shut-off cocks with removable handles are used, indicators of the direction of the passage in the plugs shall be cut into the square shank.
800. The shut-off valves installed on the discharge and suction pipelines of a compressor shall be positioned as close to it as possible and located in an area convenient for servicing.
801. The connections of compressors and their gas pipelines shall be checked systematically for leak-tightness in accordance with the intervals established by the manufacturer's instructions and the process regulations.
802. The intake air shall be cleaned of mechanical impurities by filters.
803. The supply of gas to the compressor intake shall be effected through liquid separators (separators) equipped with light and sound alarms, as well as an interlock that stops the compressor upon reaching the maximum permissible liquid level in the separator. The compressor station premises shall have a continuously operating supply-and-exhaust ventilation system, as well as an emergency ventilation system interlocked with instruments for monitoring the state of the air environment.
804. Compressors handling hydrocarbon gases shall be equipped with a system for the automatic shutdown and interlocking of the starting of the compressors upon reaching the concentrations of hydrocarbon gases in the premises established by the design documentation.
805. In the event of a disruption of the lubrication system, exceedance of the maximum permissible values of the operating parameters, or the appearance of vibration and knocking, the compressor shall be stopped immediately to identify the faults and eliminate their causes.
806. After each stopping of the compressor, the moving parts inaccessible for inspection during its operation shall be inspected and the absence of exceedance of the permissible heating temperatures verified. Faults noticed shall be eliminated immediately.
807. Starting the compressor after inspection, repair and prolonged forced shutdown (other than the standby one) shall be carried out only with the permission of the head of the facility (the foreman, the head of the compressor station) or the mechanic.
808. Compressors held in reserve shall be shut off by shut-off valves both on the intake line and on the discharge line.
809. An air compressor unit shall have standby compressors, as well as a standby electric power supply.
810. The connection of pipelines supplying air or instrument gas for measuring instruments and automation with pipelines supplying instrument gas or air for technical purposes shall not be permitted.
811. Air intake by the compressor shall be effected outside the premises in an area free of admixtures of combustible gases and dust.
812. Where several compressors operate into a common network, a check valve and a shut-off gate valve or valve shall be installed on each air line for each of them.
813. The indication of the pressure of the air supplied to the system shall be automatically relayed to the control room.
814. The territory of the installation shall be fenced, where it is not within the common fencing of the facility, and marked with warning signs.
815. The equipment of low-temperature separation units shall be purged into a closed vessel with the gas conveyed into its recovery system.
816. Discharging into the atmosphere gases containing hydrogen sulphide and other harmful substances without neutralisation or incineration shall be prohibited.
817. At least two safety devices are installed on each gas separator, each of which shall ensure the trouble-free operation of the apparatus.
818. The safety devices on the condensate collector shall be installed in the upper part of the apparatus.
819. The gas discharged by the safety devices shall be conveyed into the system or to the flare (vent stack) located outside the territory of the installation or at a distance of at least 25 m from the fencing.
820. The design of gas wells, the piping of their wellheads, the procedure for strength and leak-tightness testing, and well development shall comply with the requirements of Chapters XV, XXII, XXIII, XXVI of these Rules.
821. The automation system for the gathering, field and inter-field transport and treatment of natural gas and gas condensate shall provide for: a system for inhibiting pipeline transport; automatic shutdown of individual equipment, a process line, an installation, or a well upon emergency deviations of parameters; the connections made during the installation of equipment and pipelines shall undergo 100 per cent quality control of the connections by methods regulated by the manufacturers in the instructions for the installation and commissioning of the equipment; systems for the introduction of corrosion inhibitors and other devices to enable the realisation of anti-corrosion actions provided for by the process regulations. All systems shall be leak-tight; remote emergency shutdown of the process line of the installation from the console of the operator on duty and the transfer of the process media to the flare line or the emergency vessel; remote monitoring of the values of the process parameters and recording of the main parameters of the process; automatic regulation of the pressure of the medium in the process equipment upon deviations of the process parameters; automatic alarm signalling when the process parameters (pressure, temperature and other parameters) go beyond the permissible limits, with the delivery of warning notification signals to the location of the installations and the operator's console; monitoring of the state of the air environment at the facilities.
822. Gas and gas-condensate wells shall be equipped with an automatic cut-off valve installed on the flow line. Where a subsurface cut-off valve is present as part of the well's downhole equipment complex, the installation of a cut-off valve on the flow line is not required.
823. Field (booster) compressor stations at natural gas production facilities are additionally equipped with: an automated system for regulating the operation of the equipment within the specified parameters; an automated system for the emergency relief of the equipment with the delivery of process media into the recovery systems; an emergency notification and communication system. The level of automation of the compressor stations shall ensure the recording of the main process parameters, including: the pressure, flow rate and temperature of the medium being pumped; the state of the air environment in the premises (the concentration of explosive and harmful substances).
824. The routes of gas pipelines and gas-condensate pipelines (for each line separately) shall be marked on the ground with indicator signs.
825. At the points where gas pipelines and gas-condensate pipelines cross roads, water obstacles, ravines and railway tracks, at turning angles, at places of possible congregation of people, and at the process assemblies of the pipelines, warning signs and notices are placed. For the listed and similar places, the design documentation shall provide for actions that exclude (reduce) the hazard of releases. These design solutions shall be included in the plan of actions for the localisation and elimination of accident consequences.
826. Before a pipeline for the transport of natural gas is put into operation, the air shall be displaced from the pipeline by gas at a pressure of not more than 0.1 MPa at the point of its supply. The displacement of air by gas is deemed complete when the oxygen content in the gas leaving the gas pipeline is not more than 1 per cent according to the readings of the gas analyser.
827. Stationary and mobile power stations under the management of organisations and used by them as main, standby or emergency sources of electric power shall meet the industrial safety requirements imposed by these Rules.
828. The design, construction and operation of the gas supply system of a power station with a gas turbine drive shall be carried out in accordance with the requirements of the safety rules for gas distribution and gas consumption networks established by Rostechnadzor. The natural gas supplied to the power station shall comply with the requirements of the manufacturer of the equipment for power stations providing power for own needs, fed by associated petroleum gas as part of its recovery. The capability of these stations to operate on gas of variable component composition (of differing calorific value and hydrogen sulphide content) shall be provided for by the manufacturer.
829. The preparation of the power unit for start-up from the cold state shall not exceed two hours across the entire operating range of outdoor air temperatures.
830. The gas pipelines from the gas supply point to the power station shall be installed and equipped with fittings and instruments in accordance with the requirements of these Rules. At the entry of the gas pipeline into the premises there shall be an isolating device.
831. The enclosed premises of power stations with a gas turbine drive shall be equipped with forced ventilation, means for monitoring the gas contamination of the air environment, and an automatic system for the emergency shutdown of the gas supply (stop valves of the normally closed type) interlocked with the gas turbine drive. The spent exhaust gases shall be conveyed to a height that ensures the permissible concentration of harmful substances in the working area. The intake of air for the ventilation of the premises and for the "combustion" of the engine shall be effected outside the premises of the power station in an area of clean air.
832. The equipment and apparatus of the electrical installation shall be of explosion-proof design and earthed.
833. Disassembly of the gas turbine unit before the fuel system and the power supply of the starting engine have been shut off shall not be permitted.
834. Heating the oil in the oil system of the gas turbine drive with an open flame shall be prohibited.
835. The power station with a gas turbine drive shall be operated in accordance with the manufacturer's operating instructions. Where the power station operates in parallel with the network of the power supply organisation, a regulation (instruction) on the procedure for the relations between the parties shall be developed.
836. Chemical laboratories shall be located in free-standing buildings or shall be annexed to (built into) buildings.
837. The supply-and-exhaust ventilation in all premises of the laboratory shall be switched on before the start of work and switched off at the end of work. Where analyses are carried out around the clock, the supply-and-exhaust ventilation shall operate around the clock. Carrying out work with faulty ventilation shall be prohibited.
838. In addition to the valves and cocks at the workplaces, the gas network of the laboratory shall have a common shut-off valve located outside the premises.
839. The person responsible for compliance with the industrial safety requirements in the laboratory is the head of the laboratory.
840. When work is carried out in the laboratory, at least two persons shall be present.
841. For all types of work carried out in the laboratory, safety instructions shall be developed, which shall be kept at the workplaces.
842. Before the start of work, it shall be verified that the air in the premises does not contain gas that has penetrated through an unclosed or faulty cock of the gas pipeline. If a gas leak is detected through faulty connections or cocks and the valve of the gas pipeline, the common valve of the gas network shall be closed and the premises ventilated. At the workplace there shall at all times be at least two sets of breathing apparatus ready for use.
843. The serviceability of the gas cocks and valves shall be checked at least once a month.
844. A stock of flammable liquids, combustible liquids and gases not exceeding the daily requirement may be stored in the laboratory building. The established stock of flammable and combustible liquids may be stored in a special room (storeroom) or in special metal boxes located in the laboratory premises. Vessels containing flammable and combustible liquids shall be tightly sealed.
845. In the laboratory premises the following shall not be permitted: working without protective clothing and personal protective equipment; washing the floor with petrol, kerosene and other flammable and combustible liquids; leaving rags, towels or clothing soaked with flammable and combustible liquids; drying anything on heating pipelines and radiators; leaving spilled flammable and combustible liquids uncleaned; cleaning up spilled product while the burners are alight.
846. In premises where work with especially harmful and poisonous substances is carried out, the ventilation system shall be individual and not connected with the ventilation of other premises.
847. Work accompanied by the release of harmful vapours and gases shall be carried out in fume hoods equipped with exhaust ventilation.
848. The luminaires installed inside the fume hoods shall be of explosion-proof design. Switches and socket outlets shall be located outside the fume hood. The fume hood shall be earthed, with the earth electrode led out to the common earthing loop.
849. The fume hoods shall be equipped with a water supply and sewerage.
850. Cluttering the fume hoods with labware, instruments and laboratory equipment not related to the work being carried out at the given time shall not be permitted.
851. Glass vessels in which pressure or vacuum may form shall be protected with a cover against fragments (in the event of vessel rupture).
852. Tables on which heating with an open flame and the distillation of products are carried out shall be covered with non-combustible material and provided with an exhaust ventilation hood.
853. On the tables, during the distillation or heating of products (by gas or electric current), the storage and decanting of them, as well as the charging of apparatus with combustible substances, shall not be permitted.
854. The boiling and heating of flammable products shall be carried out in a water bath or on an electric hotplate of the closed type.
855. When carrying out work involving the flame or electric heating of combustible substances, leaving the workplace unattended shall not be permitted.
856. The residues of combustible substances after analysis, spent reagents and other substances shall be discharged into a vessel designated for that purpose. Discharging these products into the sinks of the domestic sewerage shall not be permitted.
857. If a sharp smell appears while working with flammable liquids, all burners shall be extinguished and measures shall be taken immediately to identify and eliminate the cause of the appearance of gas, and the spilled products shall be removed, the flooded areas being washed with water.
858. Washing of labware is permitted only in a specially equipped place in the premises.
859. The petroleum products required for washing labware shall be kept in sealed vessels. The storage of petroleum products in glass vessels shall be prohibited.
860. The storage and issue of poisonous and harmful substances and work with them shall be carried out in accordance with the rules and instructions for each substance.
861. In the laboratory premises, only cylinders with inert gases (nitrogen, carbon dioxide, helium, argon) may be placed, in locations that preclude their heating.
862. All vessels with compressed, liquefied and dissolved combustible gases under pressure shall be installed outside the laboratory building in metal cabinets with slots or louvred grilles for ventilation.
863. During draining and loading, the wheels of the tank cars shall be fixed on the rail track with shoes made of metal that does not produce sparks.
864. Carrying out hot work at a distance of less than 100 m from the loading rack during the placement of rail tank cars and the draining and loading of combustible products shall not be permitted.
865. Operations for the draining and loading of rail tank cars may be carried out after the locomotive has been removed from the territory of the loading rack to a distance of at least 100 m from the loading rack.
866. On the railway tracks and roads leading to the "draining-loading" section, warning notices shall be posted: "Stop", "No entry", "Loading (or draining) of tank cars in progress". In addition, the railway tracks of the loading-and-draining racks shall be equipped with a device that precludes the possibility of rolling stock entering the track on which the loading-and-draining operations are being carried out.
867. For the safe conduct of loading (draining) operations of liquefied gases and low-boiling combustible liquids (with a boiling point below the ambient temperature) into tank cars (from tank cars), measures shall be provided that preclude the possibility of vapour formation in the pipelines, cavitation, hydraulic shocks and other phenomena capable of leading to the mechanical destruction of the elements of the "draining-loading" system.
868. For draining and loading operations of liquefied gases, flammable liquids and combustible liquids into rail tank cars, the use of flexible hoses (sleeves) is permitted where the quality of the hoses complies with the operating conditions. The hoses shall be inspected daily to identify cracks, cuts, abrasions and other damage; at least once every 3 months the hoses shall undergo hydraulic strength testing at a pressure exceeding the working pressure by 25 per cent.
869. The use of flexible hoses as stationary pipelines shall be prohibited.
870. When opening and closing the hatch covers of the tank cars, the worker shall stand on the windward side.
871. Opening or closing the hatch covers of the tank cars, connecting hoses, telescopic pipes and other devices shall be done carefully, without allowing impacts.
872. Loading into the tank cars shall be effected in an even stream below the liquid level, for which the end of the hose lowered into the tank car shall reach its lower generatrix. Carrying out loading-and-draining operations during a thunderstorm shall not be permitted.
873. Loading of liquefied gas and unstable product by releasing the vapour phase into the atmosphere or to the flare shall not be permitted.
874. Loading into tank cars shall not be permitted if the residual vapour pressure of the product is less than 0.05 MPa, except for tank cars being loaded for the first time or after repair.
875. The draining and loading of tank cars shall be carried out under the direction of a responsible person appointed by the head of the structural subdivision.
876. The draining-loading work shall be performed by at least two workers. The workers carrying out the draining and loading of tank cars, as well as their draining-off, shall use gloves and shall have at the workplace (on the loading rack) appropriate respiratory protective equipment, and shall use tools made of materials that do not produce sparks.
877. Rubber hoses with metal nozzles intended for loading into road or rail tank cars shall be earthed by a wire wound around the hose on the outside or passed inside, with one end of it soldered to the metal parts of the pipeline and the other to the hose nozzle. The hose nozzles and the wire shall be made of metal that does not produce sparks.
878. The loading risers for road or rail tank cars shall have earthing devices, which are metal conductors electrically connected at one end to the earth electrode and at the other to the loading riser. They shall also have an earthing circuit monitoring device, which shall operate to shut down the pumps in the event of a break in the earthing circuit. The casings of road or rail tank cars shall be earthed before draining and loading are carried out.
879. The rails of the railway tracks within the loading-and-draining rack shall be electrically connected to one another and connected to the earthing device.
880. During the operation of field pipelines, the workers of the operating organisation shall be guided in their activities by: the design and as-built documentation; the process regulations for the operation of the field pipelines; the operational documentation.
881. The operational documentation is developed on the basis of the design and as-built documentation and the applicable regulatory legal acts and includes: a list of the field pipeline facilities; the process regulations for the operation of the field pipelines; the field pipeline data sheets; the process diagrams approved by the technical manager of the operating organisation; production instructions for maintenance and repair; orders on the appointment of persons responsible for safe operation; schedules for the maintenance, diagnostics and repair of the field pipelines; the inspection log or the watch log; reports on the technical investigation of incidents and accidents; conclusions based on the results of technical diagnostics and industrial safety expert review, field pipeline inspection reports, testing protocols (reports); logs recording incidents and accidents;
882. The organisation operating the field pipelines shall, throughout the entire period of operation of the hazardous production facility (until liquidation), keep the design and as-built documentation in the manner determined by the head of the organisation.
883. The following shall be subject to annual revision: the schedules for the maintenance, diagnostics and repair of the field pipelines; the schedules for the inspection of the linear part (including crossings) of the field pipelines; the planned volumes of repair work on the field pipelines; the list of field pipeline facilities withdrawn from operation; the list of field pipelines subject to conservation and liquidation.
884. At the stage of design, construction, reconstruction, and also operation of the field pipelines, process regulations shall be developed.
885. Field pipelines for the transport of formation fluids and gases shall be resistant to the expected mechanical and thermal stresses (loads) and chemical impact. The pipelines shall be protected against external corrosion.
886. Pipelines transporting corrosive-aggressive agents (corrosion rate greater than 0.2 mm/year) shall be of corrosion-resistant design.
887. For the connection of shut-off valves, pressure regulators and other apparatus, as well as instrumentation and control devices, flanged and threaded connections are used. The connection of pipes to the flanges of shut-off valves by welding shall not be permitted.
888. At the beginning and end of each pipeline, shut-off devices shall be installed for the emergency withdrawal of the pipelines from operation. Shut-off devices shall also be installed on hazardous sections.
889. Quality control of the welded joints of the pipelines is carried out in accordance with the requirements of the applicable regulatory acts.
890. Pressure oil pipelines and gas pipelines with an outer diameter of 159 mm and above that have sections classified as especially hazardous (crossings with water obstacles, motor roads and railways, or process communications) shall be subjected to pre-start-up in-line instrumented diagnostics or to in-line instrumented diagnostics as part of the entire pipeline, established by the design documentation. Oil-and-gas pipelines and water conduits that have sections classified as especially hazardous (crossings with water obstacles, motor roads and railways, or process communications) may be subjected to other pre-start-up instrumented diagnostics established by the design documentation.
891. Sections of underground field pipelines at the points of crossing rivers, motor roads and railways shall be laid in protective casings made of steel or reinforced-concrete pipes. The need to install protective casings at the points where field pipelines are laid across streams, marshes and lakes is established in agreement with the owners of the sections concerned.
892. The laying of above-ground and underground oil-gas-condensate pipelines through populated areas shall not be permitted.
893. The laying profile shall be self-compensating, or the pipelines are equipped with compensators, the number and type of which are determined by calculation and specified in the design documentation.
894. In areas where movements of earth masses may occur under the influence of natural and climatic features, measures shall be provided to protect the pipelines against this phenomenon. Where soils have insufficient bearing capacity, compensating actions shall prevent damage to the pipeline from settlement or heaving. Where the soil is rocky, an appropriate sheath (casing) or the laying of ballast layers shall be provided; at the same time, in the event of a sharply changing profile in mountain conditions, the laying of pipelines in troughs shall be provided for the maximum recovery of possible emergency releases of hydrocarbons and the reduction of the technogenic impact on the environment.
895. The shut-off valves on the pipelines shall be opened and closed slowly to avoid hydraulic shock.
896. On all shut-off valves of the pipelines, including those with a gearbox or a shut-off element with concealed stem movement, there shall be indicators showing the direction of their rotation: "Open", "Closed". All shut-off valves shall be numbered in accordance with the pipeline diagram.
897. Shut-off valves of field pipelines located underground shall have remote control or extended stems for their opening and closing without a person descending into the pit. Shut-off valves of oil-gas-condensate pipelines intended for the transport of product containing hydrogen sulphide shall be installed on the surface.
898. Flow lines directly connected to the wells shall be equipped with shut-off devices that cut off the flow of liquid from the well in the event of an emergency loss of tightness of the oil-gas-condensate pipeline. The use of remotely controlled shut-off devices is permitted if the parameters of the well operation are monitored remotely and the shut-off devices can be closed from the control console.
899. Before being put into operation, a section of the pipeline or the entire pipeline shall be subjected to cavity cleaning and to strength and leak-tightness tests. These operations are carried out after the full readiness of the section or the entire pipeline (full backfilling, embankment or fastening on supports, installation of the valves and instruments, cathodic leads, and submission of the as-built documentation for the object being tested).
900. The cavity cleaning and testing of oil-and-gas gathering pipelines shall be carried out in accordance with the design documentation, the process regulations or the instructions for the cavity cleaning and testing of pipelines.
901. The methods of testing and cavity cleaning of the pipelines are established in the design documentation.
902. Before the start of purging and testing of a pipeline with gas or air, the hazardous zones in which the presence of persons is prohibited during such work shall be determined and marked with signs, in accordance with Table No. 1 of Appendix No. 7 to these Rules.
903. During hydraulic testing and the removal of water from pipelines after testing, hazardous zones shall be established in accordance with Table No. 2 of Appendix No. 7 to these Rules and marked on the ground with warning signs. When testing is carried out, locations shall be provided for the safe removal of liquid from the pipeline and for its disposal.
904. When purging a pipeline, the minimum distances from the point of gas release to structures, railways and highways, and populated areas shall be taken in accordance with Table No. 1 of Appendix No. 7 to these Rules.
905. Purging and testing of pipelines with gas containing hydrogen sulphide shall not be permitted.
906. Pneumatic testing of pipelines shall be carried out with air or inert gas; pneumatic testing of pipelines that previously transported explosive hydrocarbon media shall be carried out with inert gas. Pneumatic testing of newly constructed pipelines with a working pressure above 11.8 MPa shall not be permitted.
907. To monitor the condition of the pipeline during purging or testing, line patrolmen provided with two-way communication with the person in charge of the work shall be assigned, who shall: keep watch over the section of the pipeline assigned to them; prevent the presence of people and animals and the movement of vehicles within the hazardous zone and on roads closed to traffic during the testing of aboveground or underground pipelines; immediately notify the person in charge of the work of all circumstances that impede the purging and testing or that create a threat to people, animals, structures and vehicles located near the pipeline.
908. The supply of inert gas or steam to pipelines for purging shall be carried out by means of removable pipeline sections or flexible hoses, with shut-off valves installed on both sides of the removable section; upon completion of purging, these pipeline sections or hoses shall be removed, and blanking plugs shall be installed on the shut-off valves.
909. Testing of a gas pipeline with gas in the zone where it crosses a railway or a motor road, or where the protective zone of the gas pipeline extends into the territory of a populated area or an economic facility, shall be carried out in accordance with the design or other documentation and with the process regulations agreed with the organisation operating the section of the railway or motor road at the points of crossing with the gas pipeline, or with the administration of the populated area or economic facility.
910. The linear part of field pipelines shall have a security zone, the dimensions of which are established by the design documentation.
911. Within the territory of the security zone of oil and gas pipelines, the construction of wells, pits and other excavations not provided for by the design documentation shall not be permitted, with the exception of excavations carried out during repair or reconstruction under the operating organisation's work execution plan. Ploughing and cultivation of land during agricultural work is permitted with the written authorisation of the operating organisation. Within security zones, the placement of permanent and temporary capital construction facilities, buildings, constructions and structures shall not be permitted, nor shall the performance of other actions that interfere with the normal operation of the pipeline and that make it difficult for the operating organisation to carry out its maintenance, inspection and repair. The design, construction, reconstruction, maintenance, routine and major repair, mothballing and decommissioning of engineering and technical support networks and linear facilities at the sections crossing the security zones by organisations and private persons are carried out subject to agreement with the organisation operating the pipelines.
912. The operation of pipelines shall be carried out at the parameters provided for by the design documentation and reflected in the technical data sheet.
913. The operation of pipelines intended for pumping explosive, fire-hazardous and aggressive gases and products shall be prohibited where clamps and other devices used for sealing pipelines under field conditions are present. The temporary installation of clamps on pipelines to prevent the spreading of liquid before the start of repair is permitted. Before repair work is performed on operating pipelines, actions ensuring the safety of the repair work shall be carried out.
914. During preventive examinations of oil and gas pipelines, the line patrolman shall be prohibited from descending into wells and other excavations within the territory of the security zone.
915. Periodic monitoring of the condition of the insulation coating of pipelines (with the exception of its offshore part) is carried out using existing diagnostic methods that allow damage to the insulation to be detected without excavating the ground, according to a schedule approved by the technical manager of the operating organisation.
916. The embedding of welded joints and flanged and threaded connections of pipelines into walls, floor slabs and foundations shall not be permitted. The points where pipelines pass through the internal walls of premises shall have sleeves and sealing devices.
917. The need for thermal insulation of pipelines against freezing and, in certain cases, their fitting with heating shall be determined by the design documentation.
918. Where sections of insulation soaked with a combustible substance are detected, measures shall be taken to prevent its spontaneous ignition (remove the soaked insulation, supply steam).
919. Non-operating pipelines (disconnected from the process flow scheme) shall be shut off, emptied of product and blanked.
920. Shut-off valves on the filling and discharge process pipelines shall be installed directly at the vessels.
921. Gate valves shall be installed on all process pipelines before their entry into the liquefied gas vessel park.
922. Identification signs shall be installed along the route of the underground liquefied gas process pipeline every 50 m on straight sections of the pipeline and at each of its turns.
923. Liquefied gas process pipelines shall not have connections with pipelines through which any other liquids and gases are transported.
924. The supply of steam to liquefied gas process pipelines for their purging shall be carried out by means of removable pipeline sections or flexible hoses, with shut-off valves installed on both sides of the removable section. Upon completion of purging, these pipeline sections or hoses shall be removed, and blanking plugs shall be installed on the shut-off valves.
925. Maintenance of the field pipeline includes: examination of the field pipeline route (observation of the condition of the field pipeline route and of the pipeline elements and their parts located on the surface of the ground), including by means of unmanned aerial vehicles for the timely detection of hazardous situations threatening the integrity and safety of the field pipeline and the safety of the environment; servicing of the technical devices and electrochemical protection facilities of the field pipeline; inspection of the field pipeline; survey of crossings over natural and artificial obstacles.
926. The frequency and scope of the maintenance work on the linear sections of the field pipeline, and of the technical devices forming part of the field pipeline, are established by the operating organisation, taking into account the requirements of the manufacturers' operating manuals. The work shall be carried out within the periods established by the annual schedules approved by the technical manager of the operating organisation.
927. Examination of the field pipeline route shall be carried out to monitor the condition of the security zone, the serviceability of the equipment, technical devices and the adjacent territory, and to identify factors that create a threat to the safety and reliability of the operation of the field pipeline.
928. The frequency of examination of the field pipeline route shall be determined by the operating organisation, with an increased frequency of examination during the flood period.
929. Examination of the field pipeline route shall be carried out by one of four methods: aerial examination; ground examination from vehicles (including watercraft when patrolling underwater and overwater crossings); ground examination carried out on foot; continuous video monitoring.
930. During examination of the field pipeline route, particular attention shall be paid to: the presence of signs of leaks; the readings of the instruments by which the pressure in the field pipeline is monitored and the comparison of the readings with the parameters established by the process regulations of the field pipeline; the condition of the welded and flanged connections and shut-off valves; the detection of exposed sections of the field pipeline; the condition of crossings over natural and artificial obstacles; the condition of bank protection works and the formation of washouts and scour; the condition of structures along the route (linear wells, protective anti-corrosion structures, roads along the route, indicator signs); construction and earthworks, including those carried out by third-party organisations; the presence of unauthorised tie-ins; the appearance of crossings of the field pipeline route not provided for; the condition of the protective casings of the field pipeline, and the condition of the insulation on the exposed (visible) sections of the field pipeline.
931. During external examination of beam, suspension and arch aboveground and overwater crossings, visual monitoring shall be maintained of the general condition of these crossings, the shore and intermediate supports, their settlement, the condition of the masts, cables, guy ropes, banks within the strip of the overwater crossings, bank protection structures, drainage ditches, the points where the field pipeline emerges from the ground, and the fastenings of the field pipeline in the supports of earthen embankments.
932. Passageways, access roads, crossings over the field pipeline and roads along the route for servicing the field pipeline shall be maintained in serviceable condition.
933. Persons carrying out the examination shall immediately report to the responsible official any leaks noticed, unauthorised tie-ins, faults and damage to structures along the route that threaten the normal operation of the field pipeline or the safety of people and of nearby organisations, populated areas and the environment. 934 When aerial examination is carried out, data on activity threatening the field pipeline or on the performance of construction work in the immediate vicinity of the field pipeline shall be verified on the ground.
935. The results of the examination shall be entered in the examination log by the person who carried out the examination.
936. Unscheduled examinations shall be carried out after natural disasters, abnormal floods, in the case of visual detection of a leak of oil, gas or water, detection of a pressure drop in the field pipeline according to the readings of the monitoring instruments, a reduction in the volumes of the transported medium, or a change in the transportation scheme.
937. Based on the results of the examination, the non-conformities identified shall be eliminated on the spot. Where it is impossible to eliminate the non-conformities on the spot, actions for their elimination are developed.
938. Where underground utilities and structures not indicated in the design documentation (documentation) are discovered at the work site, the work shall be immediately stopped, and measures shall be taken to ensure the preservation of those utilities and structures, to establish their ownership and to summon a representative of the operating organisation.
939. In the event of damage to the field pipeline or detection of a product leak during the performance of work by a third-party organisation, the personnel and technical equipment shall be immediately withdrawn beyond the boundaries of the hazardous zone, and the organisation operating the field pipeline shall be notified of the incident.
940. Until the arrival of the emergency recovery crew, the person in charge of the work shall take measures to prevent access to the hazardous zone by unauthorised persons and vehicles.
941. Workers carrying out examination or servicing of engineering utilities and facilities located in the area through which the field pipeline passes, as well as citizens who have discovered damage to the field pipeline or an escape (leak) of the transported medium, shall immediately report this to the dispatch or emergency service of the organisation operating that section of the field pipeline.
942. Where damage to the field pipeline or a product leak threatening facilities, buildings and structures operated by other organisations and the environment is detected, information on the possible development of hazardous factors shall be transmitted by the dispatch service of the organisation operating the field pipeline to the organisations owning those facilities, and also to the relevant authorities and administrations.
943. The design depth of laying of the field pipeline shall be maintained along the entire route. Where exposure, sagging or scour of sections of the field pipeline occurs, they shall be repaired in accordance with the requirements of the design documentation. The actual depth of laying of the field pipeline shall be periodically monitored during the inspection of the field pipeline.
944. All sections of the field pipeline shall be accessible for the performance of preventive, repair and emergency work. The method of access is determined by the design documentation or the process regulations, and also by the action plan for the localisation and elimination of the consequences of accidents.
945. All shut-off valves of the field pipeline, including those having a reduction gear or a shut-off element with concealed stem movement, shall have indicators showing the direction of their rotation: "Open", "Closed". All shut-off valves shall be numbered in accordance with the diagram of the field pipeline.
946. The sites of the shut-off valves and wells within the enclosures shall be graded and protected against flooding by surface and ground water in accordance with the design documentation.
947. Unobstructed access for workers to the control units of the shut-off valves shall be ensured. The servicing platforms shall be kept clean and in serviceable condition. Opening and closing of the shut-off valves is permitted by order of the responsible person, with a record in the examination log or the watch log.
948. Operations for controlling the shut-off valves and for their maintenance, as well as keeping the technical devices and equipment in serviceable condition, shall be carried out in accordance with the requirements of the manufacturers' instructions.
949. Maintenance of the electric heating system of the field pipeline shall be carried out before seasonal switching-on.
950. Maintenance of the electrochemical protection facilities of the field pipeline shall include periodic technical examination of the protection elements and a check of its operating mode in accordance with the schedules approved by the technical manager of the operating organisation.
951. Maintenance of the electrochemical protection installations (unless otherwise established by the design documentation and the technical documentation) includes: a check of the condition of the protective earthing circuit (repeated earthing of the neutral conductor) and of the supply lines (by external examination, the reliability of the visible contact of the earthing conductor with the housing of the electrical protection installation, the absence of a break in the supply wires on the support of the overhead line and the reliability of the contact of the neutral conductor with the housing of the electrical protection installation are checked); examination of the condition of all elements of the cathodic protection equipment to establish the serviceability of the fuses, the reliability of the contacts, and the absence of traces of overheating and scorching; cleaning of the equipment and contact devices from dust, dirt and snow, a check of the presence and conformity of the reference marks and of the wells of the contact devices; measurement of the voltage, the magnitude of the current at the converter output, and the potential on the protected field pipeline at the connection point with the electrochemical protection installation switched on and switched off (where the parameters of the electrical protection installation do not conform to the commissioning data, its operating mode shall be adjusted); elimination of breaks in the drainage lines; measurement of the potential of the sacrificial anode relative to the ground with the sacrificial anode disconnected; measurement of the "field pipeline-ground" potential with the sacrificial anode switched on and switched off; measurement of the magnitude of the current in the "sacrificial anode - protected structure" circuit. The condition of the adjustable and non-adjustable jumpers shall be checked by measuring the "structure-ground" potential difference at the jumper connection points (or at the nearest measuring points on the underground structures), and also by measuring the magnitude and direction of the current (on the adjustable and detachable jumpers).
952. When checking the effectiveness of the operation of the electrochemical protection installations, in addition to the work carried out during the technical examination, measurement of the potentials on the protected field pipeline shall be performed at the reference points (at the boundaries of the protection zone) and at the points located along the field pipeline route that are established in the design and process documentation.
953. The polarisation protective potential of the insulated field pipeline shall conform to the requirements established by the design documentation (documentation).
954. The results of the electrochemical protection monitoring shall be entered in the electrochemical protection monitoring log with an indication of the minimum permissible potential.
955. The field pipeline route on the ground shall be marked with sign boards installed at a height of 1.5 - 2 m from the surface of the ground within direct line of sight every 500 - 1000 m, and also at turning angles and crossings with other field pipelines and utilities. The sign board is installed 1 m from the axis of the underground field pipeline or on its axis.
956. The following information shall be provided on the sign board: the purpose and name of the field pipeline or of a structure forming part of it; the location of the axis of the field pipeline from the base of the sign; the reference of the sign on the route (the kilometre or chainage of the route); the security zone of the field pipeline; the telephone numbers of the organisation operating the field pipeline.
957. The field pipeline route at the locations of crossings over natural and artificial obstacles, at shut-off valve units and on hazardous sections shall be marked on the ground with permanent identification and warning signs.
958. The signs at crossings of motor roads and railways and the rules for their installation shall meet the requirements of the operating rules of the respective transport routes and of the national standard for signs.
959. The frequency and scope of the inspection of the field pipeline are established by the documentation of the operating organisation depending on the rate of the corrosion and erosion processes, taking into account the experience of operating similar field pipelines, the results of the external examination, the previous inspection and the need to ensure safe and failure-free operation in the period between inspections, but not less than once every 8 years.
960. The first inspection of newly commissioned field pipelines shall be carried out not later than 1 year after the start of operation of the field pipeline.
961. The operating organisation shall annually prepare schedules for the performance of the inspection work on the field pipeline.
962. During inspection of the field pipeline, the following shall be performed: a visual survey of the field pipeline route and of all natural and artificial obstacles, with reference to the route chainages; determination of the depth of embedment of the field pipeline; determination of the locations for non-destructive testing (not fewer than two sections per 1 km; for a field pipeline less than 500 m in length, not fewer than two trial pits per facility shall be made). The sections are selected at the most hazardous locations: exposed areas, stagnant zones (dead-end and temporarily non-operating sections), at locations where the direction of flow changes (bends, transitions, tees, tie-ins) and shut-off valve units. Where necessary, trial pitting is carried out. The dimensions of the trial pits shall provide full access to the field pipeline over its entire surface, including the lower generatrix, over a length of not less than 1 m; the referencing of the non-destructive testing locations to the route chainages (for the purpose of monitoring the change in the wall thickness of the field pipeline during subsequent inspections, locations with the previous route chainage coordinates shall be used); determination of the technical condition of the technical devices; determination of the diameter of the field pipeline; visual examination of the external protective (anti-corrosion) coating (determination of the presence (absence) of external mechanical and corrosion damage, measurement of the geometric parameters of the damage found using measuring instruments (a ruler, a welder's gauge); ultrasonic wall thickness measurement of the field pipeline or in-line diagnostics; determination of the integrity of the protective coating at the monitoring locations (if the field pipeline has factory insulation, consideration shall be given to the possibility of monitoring the wall thickness with instruments that allow measurements to be made through the insulation layer); ultrasonic (radiographic) monitoring of the quality of the welded joints where welded seam defects are suspected based on the results of the visual and measurement inspection; determination of the presence or absence of stray currents; determination of the locations of insulation damage; survey of the sections where the field pipeline crosses natural and artificial obstacles within the security zone, including trunk oil pipelines and gas pipelines; determination of the rejection wall thickness of the field pipeline; determination of the rate of corrosion and erosion wear and calculation of the corrosion rate.
963. Where an unsatisfactory condition of a section of the field pipeline is revealed as a result of the inspection, measures shall be taken to repair that section of the field pipeline.
964. On the basis of the data obtained from the results of the inspection, an inspection report is drawn up by the organisation that carried out the inspection, in which a conclusion on the technical condition of the field pipeline is made.
965. Where hazardous defects are detected on the field pipeline that lead to a loss of tightness of the field pipeline, the operating organisation shall immediately take measures to eliminate them.
966. Defects detected during the inspection shall be eliminated in accordance with the actions approved by the technical manager of the operating organisation.
967. Inspection of the field pipeline is carried out by workers of the operating or contractor organisation with the involvement of a certified non-destructive testing laboratory.
968. In-line diagnostics shall be carried out on the field pipeline provided that there is technical feasibility as determined by the design documentation (documentation). When in-line diagnostics is carried out, ultrasonic wall thickness measurement is performed only to confirm defects as part of additional flaw-detection monitoring.
969. Work involving the loading, launching, receiving and extraction of in-line tools shall be carried out under the control of a responsible person of the operating organisation appointed by order.
970. Technical reports (conclusions) on the results of the diagnostics shall be stored at the operating organisation together with the data sheet of the field pipeline throughout the entire service life of the field pipeline. Data on the repairs carried out shall be entered in the data sheet of the field pipeline.
971. Levelling of the aboveground sections of the field pipeline shall be carried out to determine the deformations and vertical displacements of its pile supports. Levelling and measurement of the deformation of the pile supports shall be carried out during the construction and operation period until the conditional stabilisation of the deformations established by the design documentation (documentation) is achieved.
972. Measurement of the deformations of pile supports that are in operation shall be carried out in the case of the appearance of impermissible cracks, deformation of welded seams, an abrupt change in the operating conditions of the field pipeline, and also during the inspection.
973. For the measurement of the vertical displacements of the pile supports, benchmarks (initial geodetic marks of the elevation base) and deformation marks (control geodetic marks placed on the supports or in the foundation soils, for which the vertical displacements are determined) are established.
974. In the case of detection of deformations of pile supports throughout the entire construction period or during the operation period, actions shall be developed for the periodic measurement of the deformation and for achieving the conditional stabilisation of the deformations established by the design documentation.
975. The survey of crossings over water obstacles shall be carried out annually within their boundaries.
976. During the survey of the underwater crossings of the field pipeline, the following shall be performed: a check of conformity with the design, as-built and operational documentation for the field pipeline; monitoring of the condition of bank protection works (where present) and of the safety signs (for navigable rivers, the condition of the "Do not drop anchor" sign is checked); determination of the presence (absence) of leaks of the transported medium; determination of the position of the field pipeline (visual examination), and of the presence and magnitude of exposures and sags; ultrasonic wall thickness measurement at the location of the non-destructive testing within the boundaries of the underwater crossing of the field pipeline; examination of the protective casing.
977. Where hazardous defects are detected in the alignment of the underwater crossing, measures shall be taken immediately to eliminate them.
978. On underwater crossings over navigable and non-navigable rivers with a water surface width at low water of 25 m or more, the following work shall be carried out not less than once every 4 years: referencing of the location of the underwater crossing to the route chainages; setting out of the sounding alignments; determination of the condition of the ballasting and insulation on the scoured sections of the field pipeline; determination of the direction and speed of the current; construction of the longitudinal profile of the crossing (with an indication of the depth of the water body and the embedment of the field pipeline and the chainage), monitoring of the condition of the protective coating.
979. The condition of the crossing of the field pipeline is deemed serviceable under the following conditions: the burial of the field pipeline in the bed along the entire length of the channel section conforms to the design and regulatory requirements; the bed is stable and the banks are practically non-deformable; the ballasting, anti-corrosion insulation and wall thickness conform to the requirements of the regulatory technical documents; there are no leaks of the transported medium into the environment; the condition of the information signs and benchmarks conforms to the requirements of the regulatory technical documents; the condition of the protective casing conforms to the regulatory requirements. The condition of the crossing is deemed unserviceable under the following conditions: the presence on the field pipeline of exposed and sagging sections; damage to the anti-corrosion insulation; the presence of vibration of the field pipeline under the effect of the current; a reduction of the wall thickness of the field pipeline to the rejection thickness; the presence of cracks and points of product leakage; the absence of part of the ballast weights and disturbances in their arrangement; a lowering of the bed levels in the crossing zone by more than 0.5 m; significant damage to the bank fastening in the underwater part with exposure of the field pipeline.
980. On the basis of the data obtained during the survey, a report is drawn up, in which a conclusion on the technical condition of the crossing is made.
981. The survey of crossings over public railways and motor roads shall be carried out annually within their boundaries.
982. The survey of crossings over public railways and motor roads for field pipelines laid by the method of directional drilling, and also of crossings of non-public motor roads, shall be carried out as part of the general inspection work.
983. During the survey of crossings of the field pipeline over railways and motor roads, the following shall be monitored: the burial of the sections of the field pipeline and the minimum distances from the ends of the protective sleeve (casing) for conformity with the design documentation; the condition of the exposed (visible) parts of the sleeves (casings) of the field pipeline, the lining, the supports, the sealing collars, the vent candles, the distances from the vent candle to the axis of the field pipeline, to the axis of the outermost railway track and to the base of the roadbed of the motor road; the condition of the inspection and drainage wells and the drainage ditches for the detection of oil leaks, disturbances of the ground cover, and subsidence and heaving of the soil hazardous to the field pipeline at the points where the field pipeline crosses railways and motor roads of all categories, and also the installation of signs prohibiting the stopping of vehicles.
984. On the basis of the data obtained during the survey, a report is drawn up by the operating organisation, in which a conclusion on the technical condition of the crossing of the field pipeline is made.
985. Pipes and parts of the field pipeline shall be subject to rejection in cases where: as a result of the inspection it has been established that, under the effect of corrosion or erosion, the wall thickness of the field pipeline has decreased and reached the critical value established in the design documentation, but not less than that in Table No. 1 of Appendix No. 8 to these Rules. during the survey of the welded seams, defects not subject to correction have been found.
986. Flanges are rejected in the case of an unsatisfactory condition of the mating surfaces, the presence of cavities and cracks, or a reduction of the wall thickness of the flange neck to the rejection dimensions of the pipe.
987. Cast worn bodies of gate valves, cocks and valves and cast parts of the field pipeline shall be subject to rejection in cases where: the sealing elements of the valves do not ensure the conduct of the process and it is impossible to repair or replace them; the wall thickness of the valve body has reached values equal to or less than those indicated in Table No. 2 of Appendix No. 8 to these Rules.
988. Strength tests and leak-tightness checks shall be carried out: to assess the technical condition of the field pipeline on which the possibility of applying non-destructive testing methods is absent or limited, at the frequency of the inspections; after replacement of a section of the field pipeline during major repair, reconstruction or technical re-equipment; after accidents.
989. Strength tests of the field pipeline and leak-tightness checks of the field pipeline are carried out in accordance with an instruction (actions) developed taking into account the specific features of the particular field pipeline and approved by the technical manager of the operating organisation.
990. The test parameters (the length of the section, the test pressure, the holding time under the test pressure and the cyclicity of the pressure changes during the tests) shall be established by the operating organisation (where necessary, jointly with a specialised organisation), taking into account the technical condition of the field pipeline, the laying conditions, the route profile, the physical and chemical properties of the pipe material and other data characterising the operating conditions of the field pipeline. If in-line diagnostics work has been carried out on the section, then strength tests and leak-tightness checks are not required to be performed.
991. The field pipeline is deemed to have passed the strength test and the leak-tightness check if, during the strength test of the field pipeline, the pipe did not fail and, during the leak-tightness check, the pressure remained within the permissible limits and no leaks were detected.
992. Damage to the field pipeline identified during the tests shall be eliminated immediately, with information on its elimination being entered in the data sheet of the field pipeline.
993. After the elimination of the damage, the tests of the field pipeline are continued according to the approved programme. The nature of each defect or damage of the field pipeline identified during the tests, as well as the work for its elimination, shall be reflected in the report.
994. The results of the test shall be formalised in a report and entered in the data sheet of the field pipeline.
995. It is permitted not to carry out the testing of the entire field pipeline after replacement of its section, provided that the section itself passed the test before being tied into the field pipeline, and the guarantee joints (the points of connection to the field pipeline) were subjected to double non-destructive testing.
996. On field pipelines equipped with launching and receiving units for cleaning and diagnostic devices, cleaning of the internal cavity of the field pipeline by passing cleaning tools through it shall be carried out to maintain the throughput capacity and to prevent the accumulation of water and internal deposits, and also to prepare the section of the field pipeline for in-line inspection.
997. The frequency of cleaning of a field pipeline by cleaning devices is determined individually for each field pipeline depending on the features of its operation and the properties of the transported medium, on the basis of schedules approved by the technical manager or a person authorised by him of the operating organisation.
998. Responsibility for the organisation and performance of field pipeline cleaning work and for monitoring the fulfilment of cleaning plans rests with the operating organisation.
999. Field pipeline cleaning work shall be carried out in accordance with instructions or activities developed by the operating organisation and approved by the technical manager of the operating organisation.
1000. The cleaning devices used shall have a set of permit and operational documentation.
1001. Switching of process lines during the launch, passage and receipt of cleaning devices is carried out by workers only on the instruction of the person in charge of the work.
1002. During cleaning, the following shall be strictly prohibited: the performance of any repair and construction work in the protection zone of the field pipeline; the presence at the sites of the launching and receiving units of cleaning and diagnostic devices of persons not involved in the cleaning work; the crossing of the field pipeline route by vehicles and machinery.
1003. When carrying out work on the launching and receiving of cleaning and diagnostic devices, the receiving and launching sites for cleaning and diagnostic devices shall be equipped with a structure preventing the ejection of the cleaning device beyond the limits of the site, as provided for by the design documentation.
1004. Based on the results of the analysis of data obtained during external inspections, examinations and the investigation of accidents and incidents over the entire operating life of the field pipeline, the selection of the type and method of repair and the determination of the scope of work and the time frame for its performance are carried out depending on the nature of the defects and the repairability of the field pipeline, taking into account its loading for the period under consideration and in the future.
1005. Based on the results of the assessment of the technical condition, the following types of field pipeline repair are planned: current repair of short sections with cutting out of defective areas or pipes and installation of spools or pipe sections with restoration of the load-bearing capacity of the pipes (repair without cutting out); selective repair of insulation; overhaul, reconstruction and technical re-equipment of the field pipeline with replacement of individual sections or of the entire field pipeline.
1006. In current repair of field pipeline defects, the following current repair methods are applied: grinding; welding-up; cutting out of the defect - replacement of the spool, pipe or string; installation of a repair structure. Welded joints made during the performance of the work shall be subject to quality control by non-destructive testing methods.
1007. Before carrying out repair work involving the installation of spools or pipe sections, the field pipeline being repaired shall be emptied of the transported medium.
1008. The section of the field pipeline to be repaired shall be isolated by gate valves and blanks from other field pipelines, apparatus and equipment, ensuring the safe performance of the work.
1009. The use of repair structures that do not have marking and certificates for the materials used shall be prohibited.
1010. All information on the repairs carried out is entered in the passport of the field pipeline with reference to the route chainage points.
1011. These Rules apply to vertical steel welded cylindrical tanks with a capacity of 100 to 50 000 m3, intended for the collection, storage and treatment of crude and commercial oil, and also for the collection and treatment of water before its injection into the formations.
1012. The choice of the type of tank, its internal equipping, anti-corrosion coating and method of installation is substantiated by the design documentation depending on the capacity, purpose, climatic conditions and characteristics of the media, and also taking into account the maximum reduction of losses.
1013. Tanks shall be equipped with: breather valves, safety valves, flame arresters, level gauges, samplers, level alarms, devices for preventing outflow (flappers), receiving and dispensing branch pipes, a clean-out branch pipe, ventilation branch pipes, and hatches (a light hatch, a gauging hatch) in accordance with the design documentation and the process regulations for the given hazardous production facility.
1014. The breather fittings installed on the tank roof shall correspond to the design overpressure and vacuum.
1015. Tanks into which, at a negative ambient air temperature, oil or water with a temperature above 0 °C enters are equipped with non-freezing breather valves.
1016. The vertical welds of the first course of the tank wall shall not be located between the receiving and dispensing branch pipes; the welds attaching individual equipment elements shall be located no closer than 500 mm to one another and to the vertical joints of the wall, and no closer than 200 mm to the horizontal joints.
1017. Single-wall tanks or groups of tanks shall be enclosed by a continuous embankment or by walls designed for the hydrostatic pressure of the spilled liquid in the event of destruction of the tank. The volume free of development inside the enclosure shall be not less than the volume of the largest tank in the group. The placement of gate valves inside the bund shall be prohibited, except for shut-off and root gate valves installed directly at the tank and intended only for servicing the given tank. Wells and gate valve control chambers shall be located on the outer side of the bund.
1018. The territory of the tank farms and the sites inside the bund shall be clean, cleared of soil impregnated with the stored products and of dry grass.
1019. On the territory of the tank farm, only explosion-proof portable luminaires (accumulator and battery type) may be used. The switching on and off of the luminaires shall be carried out outside the bund of the tank farm.
1020. Simultaneous automatic switching of gate valves in the tank farm may be carried out only provided that the pipelines are protected against overpressure.
1021. Where electrically driven gate valves with local or remote control are present, alarm signalling indicating the position of the shut-off element of the gate valve shall be provided.
1022. It shall be prohibited to pump into vessels (tanks) a product with a vapour pressure greater than that for which they are designed (the permitted working pressure).
1023. External inspection of earthing devices shall be carried out together with the inspection of the equipment of the vessels (tanks), but not less than once every 6 months. Inspections with selective opening of the ground in the places most subject to corrosion shall be carried out in accordance with the schedule of planned preventive maintenance, but not less than once every 12 years. The size of the section of the earthing device subjected to selective opening is determined by the decision of the technical manager of the organisation. To carry out measurements of the resistance of the earthing device, the possibility of disconnecting the earthing conductor at a convenient location shall be provided. Disconnection of the earthing conductor shall be possible only with the use of a tool.
1024. It shall be prohibited to operate vessels (tanks) with defective stairways and service platforms.
1025. The putting into operation of vessels (tanks) after surveys, examinations and repair shall be carried out with the written permission of the responsible person in whose charge the tank farm is.
1026. The volumetric rate of filling and emptying of a tank shall not exceed the throughput capacity of the breather valves specified in the process chart of the tank.
1027. Where a steam coil is located inside a tank, a device for draining condensate from it shall be provided. Steam coils shall be secured on supports. The joining of the coil pipes shall be carried out only by welding.
1028. Measurements of the level of oil and petroleum product and the taking of samples in tanks with an overpressure in the gas space of up to 200 mm water column may be carried out manually through an open gauging hatch.
1029. During manual sampling, samplers that do not produce sparks shall be used. The sampler shall be certified and have an earthing multi-strand copper cable. The gauging hatch shall be located at a distance of not more than 0.5 m from the edge of the platform. An earthing point for the sampler shall be provided on the platform.
1030. The gauging hatch on tanks shall be provided with a sealed cover with a pedal for opening by foot. The covers shall have gaskets made of materials that do not produce sparks (for example, copper, lead, rubber).
1031. When opening the gauging hatch, measuring the level, taking samples, and also when draining tanks, one shall stand on the windward side. It shall be prohibited to look into an open gauging hatch.
1032. To avoid spark formation during measurements with a steel tape, the opening of the gauging hatch shall have, along its inner perimeter, a ring made of a material that does not produce sparks during the movement of the measuring tape.
1033. The plumb bob of the measuring tape for measuring the level shall be made of a metal that does not produce sparks.
1034. After the completion of level measurement or sampling, the cover of the gauging hatch shall be closed carefully, not allowing the cover to fall and strike against the neck of the hatch.
1035. The flight stairways of tanks shall have a slope of not more than 50°, and the width of the stairways shall be not less than 65 cm. The distance between the steps in height shall be not more than 25 cm. The steps shall have an inward slope of 2° - 5°. On both sides, the steps shall have side strips or side skirting not less than 15 cm high, precluding the possibility of a person's feet slipping. The stairways shall be equipped on both sides with railings 1 m high. The upper platform of the stairway shall be at the same level as the upper angle or channel of the tank.
1036. On tanks that do not have railing guards around the entire circumference of the roof, railings not less than 1 m high, adjoining the railings of the stairway, shall be arranged along the edge of the roof up to the locations of the tank equipment.
1037. The base of the tank shall be protected from erosion by surface water, for which a constant drainage of water through the sewerage to the treatment facilities shall be ensured.
1038. The discharge of contaminants into the sewerage after the cleaning-out of tanks shall be prohibited. The waste water generated during the cleaning-out of tanks is discharged through demountable pipelines into sludge collectors.
1039. Tanks with a stationary roof, at a flash point of oil and petroleum products of 45 °C and below, are placed in a group with a total capacity of up to 80 000 m3 with a common bund for the group and with separation inside the group by an earth embankment of tanks with a total capacity of 20 000 m3.
1040. Before putting a tank into operation, hydraulic tests are carried out, and the horizontality of the outer contour of the bottom and the geometric shape of the tank wall are checked.
1041. Tanks in operation shall be provided with: (a) a technical passport of the tank; (b) a technical passport for the pontoon; (c) a calibration table of the tank; (d) a process chart of the tank; (e) a current maintenance log; (f) a log for monitoring the condition of lightning protection devices and devices for protection against the manifestation of static electricity; (g) a diagram of the levelling of the base; (h) a diagram of lightning protection and protection of the tank against manifestations of static electricity; (i) instructions and reports for the replacement of tank equipment; (j) process charts for the replacement of tank equipment; (k) as-built documentation for the construction of the tank.
1042. Tanks in operation shall be subject to periodic survey and diagnostics, allowing the necessity and type of repair, as well as the residual service life of the tank, to be determined.
1043. Diagnostics is carried out by a specialised organisation.
1044. For crossing the bund, crossover stairways (on opposite sides) shall be provided in the number of four for a group of tanks and not less than two for free-standing tanks.
1045. For servicing the breather and safety valves, hatches and other fittings located on the roof of the tank, metal platforms connected to one another by crossings (walkways) with a width of not less than 0.65 m shall be provided. Walking directly on the roofing of the tank during its servicing shall be prohibited.
1046. Operations for the storage and movement of liquefied hydrocarbon gases and unstable condensate and for the filling and emptying of vessels and tanks shall be carried out in accordance with the requirements of the process regulations.
1047. The value of the maximum filling of vessels with product shall not exceed 83 per cent of the geometric volume.
1048. It shall be prohibited to pour product into a vessel in a free-falling stream.
1049. The liquid level, temperature and pressure of the product shall be monitored in the running (metering) vessels every 2 hours, and in the commercial (storage) vessels not less than once per shift. The results of monitoring shall be recorded in the watch log.
1050. Sampling from vessels shall be carried out by an operator who has an admission to the right of sampling, under the supervision of a chemical laboratory assistant and in compliance with the safety requirements for the performance of gas-hazardous work.
1051. The industrial effluents of oil, gas and gas condensate treatment installations shall be subjected to neutralisation, treatment and utilisation in accordance with the process regulations.
1052. Monitoring shall be carried out of the collection of waste water, the degree of its contamination, and the efficiency of operation of the treatment facilities and utilisation systems.
1053. The operation of sewerage with defective or improperly made hydraulic seals shall be prohibited. In each hydraulic seal, the layer of water forming the seal shall have a height of not less than 0.25 m.
1054. The wells of industrial sewerage (and of other purpose) on the territory of the field installation and beyond its limits shall be kept permanently closed. The covers of the wells shall be covered with a layer of sand of not less than 10 cm in a steel or reinforced concrete ring.
1055. It shall be prohibited to place wells under the racks of process pipelines and within the bunds of the equipment of outdoor installations containing explosive products.
1056. Wells in which work is carried out shall be fenced off, and near them warning signs and posters shall be posted with the inscription: "Work in progress".
1057. When emergency situations arise at the facilities for the collection, treatment and transportation of oil, gas and gas condensate, measures are taken for the safe conduct of the process operations, up to their shutdown.
1058. Preparation for repair and repair at the facilities for the collection, treatment and transportation of oil, gas and gas condensate is carried out according to plans for the safe conduct of work approved by the operating organisation.
1059. The workers of the central oil collection point shall know the layout diagram of the process pipelines and the purpose of the gate valves, so as to carry out the necessary switching without error during operation or in an emergency situation.
1060. Before starting a pump located in a room and filling it with oil, the exhaust ventilation is switched on. Starting the pump into operation with defective ventilation shall not be permitted.
1061. The purge cock of the pump for pumping oil is equipped with a tube for the discharge of oil into a collection vessel.
1062. Pumps pumping oil are equipped with an electric drive in explosion-proof design and with remote shutdown.
1063. An oil tanker vessel moored to an oil loading or transshipment complex is inspected by a responsible person appointed by the head of the hazardous production facility of the offshore oil and gas complex to determine the possibility of loading oil.
1064. The length of the hoses connecting the ship's pipeline to the loading and unloading devices of the hazardous production facility of the offshore oil and gas complex is determined from the conditions of safe movement of the moored vessel.
1065. The hoses connecting the ship's pipeline to the loading and unloading devices of the hazardous production facility of the offshore oil and gas complex are supported by means of soft slings or wooden stands, provided that their suspension and fastening are reliable.
1066. Before loading, the serviceability of the operation of the pump system, the correctness of the opening of all switching valves and gate valves, and also the serviceability of all loading and unloading devices and the tightness of the connections of the hoses or telescopic pipes are checked. Any leak detected on the loading devices is eliminated immediately.
1067. The workers of the hazardous production facility of the offshore oil and gas complex and of the oil tanker vessel maintain constant observation of the progress of the loading work and the condition of the equipment. In the event of a leak forming, the oil loading operation is suspended until the malfunction is eliminated and the spill is cleaned up.
1068. During loading work, the approach to the oil tanker vessel and the mooring to it of other vessels and floating craft not connected with oil loading operations shall not be permitted.
1069. Loading during lightning discharges shall not be permitted.
1070. The warming of frozen pipelines with an open flame shall not be permitted.
1071. If emergency repair of the oil tanker vessel is necessary, the unloading and loading operations are stopped and the vessel is moved away from the hazardous production facility of the offshore oil and gas complex to a safe distance.
1072. All persons who are to work in the confined space of apparatus, tanks and other equipment shall undergo instruction on the possible hazards, safety measures, rules for providing first aid and actions in emergency situations.
1073. The preparation of a confined space for work inside it shall be carried out by workers under the guidance of an engineering and technical worker well informed about the possible hazards.
1074. Work in a confined space shall be carried out provided that lighting is ensured in accordance with the process regulations.
1075. Before the performance of work in a confined space and work of increased hazard, a permit to work shall be drawn up.
1076. Persons having the right to issue permits to work for the performance of work of increased hazard and in a confined space are approved by the organisational and administrative documents of the organisation. These persons are appointed from among the managerial workers.
1077. Responsibility for safety, both on entry into the confined space and during the work, rests with the person who has issued the permit to work. His duties include taking measures to prevent possible hazards.
1078. The following information shall be included in the permit to work: (a) the person responsible for carrying out the work in the confined space; (b) an assessment of the possible hazards; (c) the composition of the work team (not less than three persons for work in a confined space); (d) the necessary personal protective equipment; (e) the need for rescue means and special tools; (f) the safety measures taken in the confined space; (g) the frequency and results of sampling of the air environment in the confined space; (h) the validity period of the permit to work; (i) the diagram of the installation of blanks; (j) the luminaires used; (k) a note on the completion of the instruction.
1079. To avoid the accumulation of static electricity, the equipment and vessels shall be earthed.
1080. Sludge and spent washing liquids shall be removed to a place designated for this purpose.
1081. If a confined space has a door or a hatch, they shall remain open after purging, and the space itself shall be ventilated by means of a mechanical forced ventilation system for the complete removal of mixtures of hazardous substances with air.
1082. After the confined space has been cleaned and ventilated, the mechanical ventilation system shall continue to operate so as to preclude the accidental entry into it of harmful impurities, and also for the removal of contaminants or heat arising as a result of the work performed (for example, welding and cutting, painting, application of coating).
1083. Before the admission of persons to perform work in a confined space, an analysis of the air environment shall be carried out.
1084. The taking of air samples (to determine the concentration of combustible gases, the shortage of oxygen, and the presence of hazardous chemicals and physical impurities) in a confined space shall be carried out by workers who have an admission and are trained for these purposes. The instruments used for this shall be of explosion-proof design and calibrated.
1085. Persons entering a confined space to take air samples before the start of work shall use a self-contained breathing apparatus or a hose breathing apparatus (depending on the specific conditions). The procedure for the use and the type of breathing apparatus are determined by the person who has issued the permit to work. The use of filtering breathing apparatus shall be prohibited.
1086. The procedure and frequency of sampling of the air environment shall be determined in the permit to work, and the results of the quality of the air environment in the confined space shall be entered in the permit to work and confirmed by the signature of the person who carried out the analysis.
1087. Before the admission of persons to perform work in a confined space, all equipment in the confined space driven by drives (for example, mixers) and the power sources shall be switched off, and the corresponding switches on the distribution board shall be locked and provided with warning signs.
1088. Immediately before the admission of workers into the confined space, the person responsible for carrying out the work shall question each operative about their well-being, re-instruct the entire work team on safe methods of work, check the quality and suitability for the given working conditions of the protective clothing, personal protective equipment, rescue gear and tools, and make sure that each worker knows their functions and duties.
1089. Only one person may work in a confined space.
1090. If, according to the working conditions, it is necessary for two or more persons to be in a vessel at the same time, additional safety measures shall be developed and specified in the permit to work.
1091. After a worker enters a confined space, he shall, as far as possible, lock all rotating and moving parts of the mechanisms to avoid their accidental actuation.
1092. During work in a confined space, for backup in the event of an emergency situation, not less than two observing workers, having the same gear as the person working, shall be present outside at the entrance (hatch, manhole) of the apparatus (tank).
1093. The observers located outside shall maintain constant communication with the persons working in the confined space, monitor the correct position of the hose of the hose breathing apparatus and of the intake branch pipe, and keep breathing apparatus ready.
1094. Persons entering a confined space shall put on safety harnesses approved for use with an attached signal and rescue rope.
1095. If the observer detects any malfunctions in the protective equipment or poor well-being of the worker in the confined space, the work shall be immediately stopped and the worker removed from the confined space.
1096. If a hazardous concentration of vapours of flammable liquids or gases is detected in a confined space, the work shall be immediately stopped.
1097. For each installation and facility, a procedure for the preparation of apparatus, tanks and equipment shall be developed, including diagrams for the emptying of products and harmful substances and the installation of blanks, diagrams for their steaming, washing and ventilation, and other measures ensuring the safety of those working.
1098. Apparatus, tanks and equipment subject to opening for internal inspection and cleaning shall be stopped, emptied of product, disconnected and blanked off from the operating equipment, steamed and ventilated. The duration of the steaming and purging and the necessity of washing with water and of ventilation are determined in each case individually.
1099. All pipelines connected with the apparatus, tanks and equipment subject to opening shall be disconnected by means of gate valves and blanks.
1100. The discharge of oil and petroleum products from apparatus, tanks and equipment during their preparation into the industrial sewerage shall be prohibited. The discharge shall be carried out into special (emergency) vessels.
1101. The steaming of a tank shall be carried out with one upper hatch open.
1102. Steam shall be supplied through the lower hatch by a hose, the outlet opening of which shall be located at a distance of 1/4 of the diameter of the tank towards the centre.
1103. The temperature inside the tanks during steaming shall be not higher than 60 °C. Where a floating metal pontoon is present, the upper and lower parts of the tank (above the pontoon and below it) shall be steamed separately.
1104. A tank with a synthetic pontoon is filled with water to displace the vapours. After the water has been drained from the tank, the side hatches shall be opened for ventilation.
1105. The metal tips of rubber hoses and the steam pipelines shall be earthed. The tips of the hoses shall be made of a metal that does not produce sparks.
1106. The covers of open hatches shall be attached to the hatches by one or two bolts secured with nuts.
1107. After the completion of the preparatory activities (steaming, washing and ventilation), an analysis of the air from the tank or apparatus for the content of vapours, gases and oxygen shall be carried out, with a record in the permit to work.
1108. The taking of air for analysis from tanks with a floating roof or pontoon shall be carried out from the lower part of the tank under the roof (pontoon) and from the upper part - above the roof (pontoon).
1109. Work on cleaning tanks and apparatus of dirt and deposits shall be mechanised. Workers performing the specified work shall be in hose breathing apparatus.
1110. The opening of tanks, apparatus and equipment for internal inspection and cleaning may be carried out only in the presence of the person responsible for preparing and carrying out the work.
1111. The unscrewing and tightening of nuts on the flanged joints of the hatches of apparatus, tanks (vessels), pipelines and fittings shall be carried out with nut runners with a pneumatic or hydraulic drive or with intrinsically safe spanners. During screwing up, control of the value of the torque established by the equipment manufacturer's documentation on installation, maintenance and repair is carried out.
1112. The opening of hatches on column-type apparatus shall be carried out in order from top to bottom, so as not to create an air draught through the apparatus.
1113. A tank and apparatus heated during the process of preparation shall, before people descend into them, be cooled to a temperature not exceeding 30 °C. If it is necessary to carry out work at a higher temperature, additional safety measures are developed (continuous purging with fresh air, the use of asbestos suits, heat-insulating footwear, frequent breaks in the work). Work inside a tank and apparatus at a temperature exceeding 30 °C shall be prohibited.
1114. It shall be prohibited to throw down from a height dirt and solid deposits extracted from tanks and apparatus during their cleaning. For this purpose, small-scale mechanisation devices shall be used.
1115. When cleaning apparatus through the lower hatch, a special platform shall be provided.
1116. During work at height, tanks and apparatus shall be equipped with continuous decking to prevent the falling of parts or tools onto those working below.
1117. When cleaning tanks and apparatus, tools (cleaning means) made of materials that do not produce sparks shall be used.
1118. For lighting inside apparatus and tanks, portable luminaires of explosion-proof design with lamps of a voltage not exceeding 12 V shall be used. The luminaires shall be switched on and off from the outside.
1119. If part of the product remains at the bottom of a tank to be cleaned, the tank shall be filled with water and the product that has floated up shall be pumped out.
1120. Work to clean a modular horizontal cylindrical apparatus and settling tanks of deposits shall be carried out by a hydromechanical method using a small-sized hydraulic monitor that precludes the presence of a worker inside the apparatus during the cleaning period. After cleaning, tanks and apparatus shall be washed with water.
1121. After finishing work inside a tank or apparatus, the worker shall check for the absence of foreign objects, hand over the tool and luminaire to the observers, and only after this exit to the outside.
1122. When cleaning a heat exchanger or condenser by a mechanical method, a barrier shall be erected on the opposite side and a warning sign shall be posted: "Danger zone".
1123. When cleaning by a hydraulic or chemical method, workers shall first undergo special labour safety instruction and use appropriate means of protection.
1124. Workers carrying out chemical cleaning shall be dressed in special clothing, rubber gloves and protective goggles.
1125. To remove petrol vapours from the box of a submerged condenser-cooler, the hatch shall be opened and the box ventilated. The outer surface of the tubes and the walls of the box shall be cleaned of silt and dirt with a jet of water under pressure.
1126. Descending into a box of a condenser-cooler that has not been cleaned of dirt without a hose breathing apparatus shall be prohibited.
1127. Work to clean the box of a condenser-cooler shall be carried out in the presence of not less than two observers.
1128. When descending into the box of a condenser-cooler, the internal ladder of the box shall be used. Descending into the box via the coil tubes shall not be permitted.
1129. To ensure reliable operation of installations and equipment, a system of maintenance and repair shall be established in the organisation in accordance with the manufacturer's instructions.
1130. Before carrying out repair work, apparatus, tanks and equipment shall be prepared and cleaned in compliance with the requirements of paragraphs 1116 - 1118 of these Rules.
1131. Before repair of equipment, persons responsible for organising and conducting the repair, for preparing the instrumentation, equipment and communications for it, and for performing the safety actions provided for by the plan for organising and conducting the work shall be appointed.
1132. Repair work on apparatus, tanks and equipment where increased production hazard exists or may arise may be commenced only after a permit to work has been issued specifying the persons responsible for preparing and conducting the repair work. If the repair work consists of hot work or gas-hazardous work, it shall be classified as hot or gas-hazardous work and the corresponding permits to work (for hot work and (or) gas-hazardous work) shall be issued.
1133. Repair work may be carried out after separate equipment or process units have been handed over for repair under a certificate.
1134. Before the start of repair work, posters and warning signs on the safe conduct of this work shall be posted at the workplaces.
1135. When carrying out repair work, workers shall be provided with personal protective equipment (PPE) and safety devices in accordance with the working conditions.
1136. For carrying out repair work at height, temporary staging and scaffolding shall be provided. The boards of the decking shall fit tightly against one another. For constructing the staging, boards not less than 5 cm thick shall be used.
1137. Work at height in the absence of a guarded working deck shall be performed by workers provided with fall-arrest systems for attachment to reliable structures.
1138. When carrying out repair work at height, placing tools at the edge of the platform shall be prohibited. Tools shall be stored in a special bag or box.
1139. For carrying out repair work, a written permission of the technical manager or of a person authorised by him of the organisation or section, or installation shall be issued.
1140. If gas appears, and also in the event of an accident at a neighbouring installation or facility, repair work shall be immediately stopped and the workers withdrawn from the danger zone. Work may be resumed only if, on a repeat analysis of an air sample, the gas concentration does not exceed the permissible sanitary norms.
1141. When disassembling and repairing parts of equipment, kerosene or a special non-combustible washing liquid shall be used for washing.
1142. During repair of equipment in explosion-hazardous premises, permanently operating supply-and-exhaust ventilation shall operate.
1143. Repair work shall be carried out provided that lighting is ensured in accordance with the process regulations.
1144. To eliminate defects, caulking the welded seams of apparatus, vessels and pipelines shall be prohibited.
1145. When repairing column apparatus, the disassembly of the trays shall be carried out from top to bottom. The parts of the trays shall be placed outside the column.
1146. Work to open up and repair any electrical equipment and lighting shall be carried out only by electrical engineering personnel.
1147. After repair, all apparatus, vessels and pipelines shall be pressure-tested. Testing shall be carried out until all leaks are completely eliminated.
1148. A record of the repair carried out shall be made in the equipment passport.
1149. Any correction or repair of the moving parts of a pump while it is operating shall be prohibited.
1150. Repair of a pump involving disassembly, including of the mechanical seals, may be carried out only after it has been stopped, the pressure has been relieved, it has been prepared for repair, it has been disconnected by means of gate valves, and blanks have been installed.
1151. Changing the packing of the glands without stopping and disconnecting the pump shall be prohibited.
1152. After the pump has been disconnected, its electric motor shall be de-energised at the switchgear, ensuring a visible break of the electrical circuit (by switching off the knife switch, removing the fuse element of the fuse, or moving the withdrawable element to the repair position).
1153. On the starter button of the electric motor and at the switchgear, prohibitory posters shall be posted: "Do not switch on! People at work".
1154. Prohibitory posters may be removed only after the work has been fully completed, on the instruction of the person responsible for carrying out the work.
1155. In the case of current repair that does not require opening the pump, and where the gate valves are in good order, disconnecting the pump from the pipelines by installing blanks is not obligatory. In such cases, a warning sign shall be posted on the starter button of the electric motor and on the closed gate valves: "Do not switch on! People at work", and on the gate valves: "Do not open! People at work".
1156. Repair of a pump after it has been stopped shall be begun when the temperature of the pump does not exceed 30 °C.
1157. Before assembly, all parts of the mechanical seal shall be cleaned, washed in kerosene or in a special non-combustible washing liquid and carefully inspected. Blows to the parts of the seal during assembly and disassembly shall not be permitted.
1158. Repair of a pump shall be carried out with tools that do not produce sparks.
1159. If a pump has been pumping harmful substances and alkali, then before repair it shall be washed with water. During disassembly of the pump, workers shall use closed protective goggles, gloves, special footwear, special clothing, PPE and (or) respiratory protective equipment (RPE) providing protection against the effect of chemical substances.
1160. Cluttering the passages between pumps with materials, and also with parts of the pump removed during repair, shall be prohibited.
1161. After the furnace coil has been prepared (freed of product, purged with steam or inert gas), all process pipelines have been blanked off, including the supply of liquid or gaseous fuel to the atomisers, before opening the plugs of the return bends it shall be ensured that there is no product in the furnace tubes by opening the control return bends: one in the ceiling screen and the other at the bottom of the furnace. When opening the control return bends, the worker shall stand to the side of the corresponding furnace return bend.
1162. If oil flows out through an opened control return bend, it shall be closed and the purging of the furnace coil continued.
1163. After the furnace coil has been completely freed of oil, the emergency pipeline is blanked off.
1164. Cleaning the furnace tubes of one and the same section from two sides shall be prohibited.
1165. Purging the furnace tubes with air simultaneously with other work carried out on the furnace shall be prohibited.
1166. Checking the operation of an air turbine shall not be carried out near working people. Removing an operating turbine from a tube shall be prohibited.
1167. Workers carrying out cleaning of tubes shall wear protective goggles.
1168. The manholes into the furnace shall be kept clear during repair work.
1169. The worker on duty located outside near the furnace shall ensure that all manholes for entry to and exit from the furnace and the ventilation openings are open.
1170. When working inside furnaces, the following shall be prohibited: dismantling the masonry in large blocks; chipping out slag on the furnace walls without protective goggles; cleaning the furnace tubes.
1171. Work in a furnace shall be stopped if there is a danger of collapse of the masonry or the presence of gas is detected in the furnace.
1172. After repair of furnaces, the connecting pipelines, atomisers or panel burners shall be purged with steam or inert gas.
1173. Filling gas pipelines with fuel gas is permitted after the completion of all repair work and the pressure testing of the working coil of the furnace.
1174. Repair of the electrical equipment of the electric dehydration and desalting installations shall be carried out by electrical engineering personnel authorised to work on electrical installations with a voltage above 1000 V.
1175. Repair work on electric dehydrators may be commenced only where there is a permit to work signed by the head of the installation and by the workers servicing the electrical part of the installation, and where the following actions have been performed in sequence: removal of voltage in the main circuit and also in the operating-voltage circuit; taking measures preventing the supply of voltage to the place where the work is carried out as a result of erroneous or spontaneous switching-on of the switching apparatus; posting prohibitory posters "Do not switch on! People at work" on the local buttons and remote-control keys; checking the absence of voltage and installing earthing on the internal part of the electrical equipment; posting a warning sign on the ladder of the electric dehydrator: "Enter here".
1176. Work involving the repair of electrical equipment inside an electric dehydrator shall be carried out by electrical engineering personnel.
1177. The warning signs may be removed only after the completion of the repair work, on the instruction of the person responsible for carrying out the work.
1178. Before carrying out repair work, the pipeline shall be freed of oil, condensate and gas, and purged with steam or inert gas. The temperature of the pipeline shall be not higher than 30 °C.
1179. The section of the pipeline to be repaired shall be disconnected by gate valves and blanks from other pipelines, apparatus and equipment.
1180. When disconnecting flanges, the lower bolts shall be released first.
1181. When disconnecting the flanges of pipelines for pumping harmful substances, appropriate precautionary measures shall be taken against these products getting onto the body, especially into the eyes. Workers performing this work shall use appropriate special clothing, gloves, special footwear and closed PPE and (or) RPE providing protection against the effect of chemical substances.
1182. When carrying out repair work involving the probability of gas release, the place of work shall be fenced off, and warning signs shall be posted near it: "Gas hazard".
1183. Welding and gas cutting on process pipelines without their disconnection and purging with steam or inert gas in wells having coverings, in tunnels, collectors and technical undergrounds shall be prohibited. When disconnecting pipelines, blanks shall be installed after the shut-off devices.
1184. In wells, welding and cutting may be carried out only after the complete removal of the coverings.
1185. Before the start of welding or gas cutting in wells and excavation pits, a check of the air for gas contamination shall be carried out. The volume fraction of gas in the air shall not exceed 20 per cent of the lower flammability limit or the maximum permissible concentration of the product. Samples shall be taken in the most poorly ventilated places.
1186. Repair work on pipelines in wells, trenches and other similar places is classified as gas-hazardous, except for work on pipelines of fresh industrial water.
1187. After repair, the pipeline shall be purged with inert gas or air, or washed.
1188. After repair of pipelines and shut-off devices located in trays and wells, the covers shall be closed.
1189. A record of the repair of the pipeline carried out shall be made in the passport and the pipeline repair log.
1190. Before installing blanks, a diagram for their installation shall be developed and approved by the person responsible for preparing the instrumentation, tanks, equipment and pipelines for inspection, cleaning and repair. This same diagram shall also indicate the shut-off valves to be sealed.
1191. Before a blank is installed, the apparatus (pipeline) shall be freed of oil, oil product or gas. After the blanks are installed, depending on the properties of the chemical products that were in them, it shall be washed, steamed, purged with inert gas and (or) clean air, and cooled to a temperature not higher than 30 °C.
1192. Blanks shall have shanks. The blank number, steel grade, nominal pressure and nominal diameter are stamped on the shank of the blanks, and, in its absence, on the cylindrical surface.
1193. On blanks installed on a tongue-and-groove type flange joint without a shank, the number and pressure are stamped on their surface.
1194. The thickness of blanks is selected on the basis of the maximum possible pressure, but not less than 3 mm.
1195. Blanks on the side of possible ingress of gas or product shall be mounted on gaskets.
1196. After the completion of the repair work, all temporary blanks shall be removed.
1197. The installation and removal of blanks shall be recorded in a special log under the signature of the persons who carried out their installation and removal, and shall be checked by the persons responsible for preparing and conducting the repair. Keeping the log in electronic form is permitted provided that the safe-keeping of the data is ensured and there is no possibility of entering unauthorised data.
1198. Current repair of wells means a set of works to restore the operability of downhole equipment and works to change the operating regime and method of operation of a well. Current repair includes such types of work as: equipping wells with downhole equipment when they are put into operation; converting wells to another method of operation; optimising the operating regime of wells; repairing wells equipped with submersible pumps; repairing flowing wells (inspection, replacement of tubing, wellhead equipment); repairing gas-lift wells; inspecting and replacing the equipment of artesian, absorbing and stand wells; cleaning and flushing the bottomhole and the wellbore; experimental work to test new types of downhole equipment. Work on current repair of wells shall be carried out according to plans approved by the technical manager (chief engineer) of the organisation carrying out this work and agreed with the customer.
1199. Capital repair of wells means a set of works to restore the operability of wells and to increase the oil recovery of the strata, industrial and environmental safety and the safety of subsoil use, including: restoration of the technical characteristics of casing strings, the cement sheath, the bottomhole zone, the perforation interval; restoration of the operability of a well lost as a result of an accident or incident; running and pulling of equipment for separate operation of the strata and injection of various agents into the strata; treatment of the productive stratum by physical, chemical, biochemical and other methods (hydraulic fracturing of the stratum, hydraulic sand-jet perforation, hydromechanical slot perforation, hydrochloric-acid treatment of the stratum and other technological operations); sidetracking of lateral boreholes and drilling of horizontal sections in the productive stratum (without complete replacement of the casing string and with complete replacement of the casing string without changing its diameter, wall thickness, mechanical properties); isolation of some horizons and connection of others; conversion of wells to another purpose; well investigation. Work on capital repair of wells is carried out according to plans approved by the technical manager of the organisation and agreed with the customer in accordance with the documentation for the capital repair of the well stock of the field, area, cluster.
1200. Reconstruction of wells includes a set of works to restore the operability of wells, involving a change of their design (complete replacement of the production string with a change of its diameter, wall thickness, mechanical properties). Work on reconstruction of wells is carried out according to plans approved by the technical manager of the organisation and agreed with the customer in accordance with the design for the performance of drilling operations during reconstruction of wells.
1201. The procedure for developing and the conditions for agreeing the work plan for current repair, capital repair and reconstruction of wells is established by the organisation operating the hazardous production facility. The work plan shall contain: a diagram of the tie-in of the wellhead with the casing head, blowout preventer and Christmas tree; the technical characteristics of the gland seals and the wellhead pressure during pressure testing together with the casing strings; information on the design and condition of the well; the reservoir pressures and the date of their last measurement; information on the downhole equipment; information on the presence of pressure in the inter-casing spaces; a list of the planned technological operations; the regimes and parameters of the technological processes; information on the category of the well; the gas factor; the diagram and type of blowout preventer; the density of the killing fluid and the parameters of the flushing fluid; the volume of the reserve of solution, the conditions for its delivery from the mixing unit; actions to prevent accidents, incidents and complications.
1202. The spudding of new (lateral) boreholes in cased wells is carried out in the following cases: elimination of accidents, incidents and complications (collapse of the production string, jamming of the tool, unplanned cementing of the string of drill or lift pipes and others) that arose during drilling, operation of the well or during repair work; opening up of additional productive capacities by drilling branches (including horizontal ones) from the drilled boreholes of wells; restoration of the idle well stock, including wells previously abandoned for technical or other reasons (where there is sufficient integrity of the well lining and economic expediency), for the purpose of opening up, by a new borehole, sections with unrecovered reserves of hydrocarbon raw material.
1203. When conducting work involving the spudding and drilling of lateral boreholes, the work plans shall additionally include: the interval for cutting the "window" in the production string; the technical means and work regimes for cutting the "window"; the layout of the pipe string and of the bottom of the drill string; the type of rock-cutting tool and its drive; the navigational support of the trajectory of the lateral borehole or horizontal branch; the regimes for driving the lateral borehole and utilising the drilled cuttings; the lining of the drilled borehole (running of the filter, technological rigging, jointing of the filter with the production string and other technological operations). In addition to the main work plan, additional work plans for the lining of lateral boreholes shall be drawn up, based on the results of interpretation of geophysical logging data during drilling or of the final logging.
1204. The handover of wells to the contractor for repair or reconstruction and the acceptance of wells after completion of the work are carried out in accordance with the procedure established by the operating organisation.
1205. The masts of the assembled well-repair units (the derricks of mobile drilling rigs) shall be located at a distance of not less than the height of the derrick from the protection zone of overhead power lines. The installation and operation of a hoisting unit at a distance less than the height of the derrick from the protection zone of an overhead power line or an overhead electrical network with a voltage of not more than 42 V is permitted only under a permit to work defining the safe conditions for carrying out the work.
1206. The transport of equipment to the well and construction and installation work begin when the following conditions are met: checking the readiness of the route of movement of the units (installations) and the presence of agreement with the relevant organisations on the conditions for crossing power lines, railway mains, trunk pipelines and other natural and man-made obstacles; conclusion of contracts for carrying out work with contractors (subcontractors).
1207. At all stages of work involving the repair and reconstruction of wells, the presence and functioning of the necessary instruments and control systems provided for by the work plans and the equipment operating instructions shall be ensured.
1208. During reconstruction and repair of wells, monitoring of the condition of the gas-air environment shall be carried out at the work site with recording in the monitoring log.
1209. The development and putting into operation of a repaired well is carried out in accordance with the procedure established by Chapter XXVI of these Rules.
1210. The movement of well-repair units and the transport of equipment to the well shall be carried out under the direction of a responsible person. Workers taking part in the transport of equipment shall be familiarised with the route of movement, the dangerous sections and the safety measures when passing them. The movement of equipment during snowfalls, fog, dust storms with visibility of less than 50 m and gusts of wind of more than 30 m/s shall be prohibited.
1211. Before the start of work on current repair, capital repair and reconstruction of wells, the work team shall be familiarised with the work plan, the plan of actions for the localisation and elimination of accident consequences (PMLA) and possible complications and accidents.
1212. The territory around a well undergoing repair shall be levelled and cleared of foreign objects. Underground utilities shall be clearly marked, and the gas pipelines of a gas-lift well shall be enclosed in a casing pipe. A diagram of the layout of the underground and surface utilities shall be issued to the work team not less than three days before the start of the work.
1213. The arrangement of the units, equipment and auxiliary facilities on the territory of a well undergoing repair, and its dimensions, shall correspond to the standard diagram approved by the technical manager of the organisation operating the hazardous production facility. Amenity premises shall be located at a distance of not less than the height of the mast (derrick) of the unit plus 10 m from the wellhead.
1214. Well-repair units and equipment shall be installed on mobile or stationary foundations made in accordance with the requirements of the operating instructions or the documentation for the arrangement of well clusters.
1215. The procedure for the movement of vehicles on cluster sites shall correspond to the established routes and shall be controlled by the responsible person in charge of the work. On the territory of the well and the cluster site, evacuation routes for workers and vehicles in the event of emergency situations shall be established.
1216. Work at height during the installation and repair of derricks (masts) shall be prohibited at a wind speed of more than 15 m/s, during a thunderstorm, downpour, snowfall and in icy conditions, and also during the hours of darkness without artificial lighting ensuring the safe conduct of the work.
1217. The guy ropes of well-repair units (installations) shall meet the requirements of the operating instructions and have a tension of not less than 400 - 500 kgf. The use of guy ropes consisting of separate parts and having knots is not permitted. The anchors of the guy ropes are located in accordance with the diagram specified in the passport of the well-repair unit (installation). The connection of the guy ropes to the anchors shall meet the requirements of the manufacturer's operating instructions.
1218. The injection lines are assembled from pipes and (or) high-pressure flexible hoses with quick-release connecting nuts and swivel elbows (angle pieces) and are pressure-tested to one and a half times the maximum working pressure provided for by the work plan.
1219. The flushing hose and (or) high-pressure flexible hose shall be wound with a soft steel rope of a diameter of not less than 8 mm with loops every 1.0 - 1.5 m along the entire length of the hose. The ends of the rope shall be fastened to the mating elements of the hose or to the structure of the equipment or technical device on which the mating elements of the pipeline are installed. To prevent rupture of the hose when working with it, a safety valve set to a pressure 25 per cent below that permissible for the hose shall be installed on the pump unit.
1220. Bolted connections shall exclude the possibility of spontaneous unscrewing (lock nuts shall be installed, or castle nuts shall be installed and cottered).
1221. The receiving ramps-racks are installed horizontally or with a slope of not more than 1:25. The length of the ramps-racks shall ensure the placing of pipes and rods with their ends protruding beyond the rack by not more than 1 m on each side. During transport, the racks are drawn into the initial position and secured. The chute is intended for guiding the end of a pipe during running and pulling operations. The racks shall have end (folding) posts. The ramps shall have a folding visor with a gangway. It is permitted to make the decking of the receiving ramps of corrugated iron or of boards not less than 40 mm thick. The width of the decking of the receiving ramps shall be not less than 1 m. The wooden decking of the ramps and of the work site shall not be worn by more than 15 per cent of its original thickness. For lowering pipes onto the ramps, a stand fastened to the ramps and adjustable in height shall be used.
1222. The racks of mobile or stationary receiving ramps during well repair shall ensure the possibility of placing pipes and rods in not more than six rows, and all the support posts of the rack shall be installed and the rack shall not have any deflection. To exclude the possibility of pipes rolling onto the ramps, wooden pads or metal posts shall be used.
1223. The topping-up (storage) tank shall be tied in with the wellhead in such a way that, during repair work and development of the well, a constant topping-up of fluid into the well is ensured by gravity or under force using a pump. The volume of the topping-up tank shall be not less than 4.5 m3. The topping-up tank may be stationary or mobile (a tank truck of any type) and shall be installed at a distance of not less than 10 m from the wellhead of the well undergoing repair, within the field of vision of the driller for capital repair of wells (the operator for current repair of wells). The tank (tank truck) shall be equipped with an indicating measuring device (a level gauge) having a graduation with a division value of 0.2 m3. The density of the fluid in the topping-up tank during repair work and development of the well shall correspond to the density of the killing fluid specified in the work plan. To prevent and eliminate possible gas, oil and water shows, the topping-up tank (tank truck) shall be permanently tied in with the annular space during repair of the well.
1224. When carrying out current and capital repairs of wells with a possible gas, oil and water show, the wellhead for the period of repair shall be equipped with a blowout preventer. The diagram of the installation and tie-in of the blowout preventer is agreed with the professional emergency rescue unit. After the blowout preventer is installed, the well is pressure-tested to the maximum expected pressure, but not higher than the pressure-testing pressure of the production string.
1225. Carrying out repair work on wells where the possibility of a gas, oil and water show is excluded (a field at a late stage of development, abnormally low reservoir pressures at oil fields with an insignificant gas factor) is permitted without installing a preventer unit. The standard scheme of the wellhead equipment of such wells (a suspension flange with an attached sealing ring with a gate valve and a branch pipe, or other variants) shall be agreed with the professional emergency rescue unit.
1226. The power supply of the electrical equipment of well-repair units shall be provided at a voltage of not more than 400 V.
1227. The connection of the control station to an oilfield network with a voltage of 400 V or to a mobile power station shall be made from a source with a solidly earthed neutral, using systems with a flexible five-wire cable by means of a four-contact connector with an earthing contact.
1228. Openly laid cables shall be accessible for inspection. At places of possible movement of special machinery and passage of people, warning signs are installed.
1229. The distance between laid cables and pipelines shall be not less than 0.5 m. Joint laying of pipelines and electric cables shall be prohibited.
1230. The crossing of intrafield roads by an electric cable is permitted only in pipes at a depth of not less than 0.5 m from the road bed. At these places, signs warning of the danger of damage to the underground cable shall be installed.
1231. The connection of portable luminaires and the routing of cables equipped with stationary connectors under field conditions are carried out by two workers: an electrician and a worker of the work team, or two workers of the work team who have undergone the appropriate instruction, provided that one of them has a qualification group of not lower than the second.
1232. When carrying out repair work, the following shall be earthed: the housings of generators of mobile power stations, automatic switches, lighting fixtures, electric stoves, radio sets and other electrical equipment; the frames of switchboards of control stations, control panels and control desks, and magnetic starters; the metal bases of all mobile buildings, the tool trolley, the power station, mobile well workover units, receiving catwalks and racks, tanks for kill fluid or well make-up fluid, fuel and lubricant tanks, the flow line system and other equipment that may become live if the insulation of electric cables is damaged.
1233. At wells without a mains electricity supply, electrical equipment shall be powered from a mobile power station, the capacity of which is established by the work plan.
1234. Before starting well workover operations (before raising the mast), the guy anchors of the mast (derrick) shall be tested. The test load is established for the specific type of unit in accordance with the manufacturer's rated data. Where an anchor fails to withstand the specified loads, its design, embedment depth or diameter shall be changed. Where anchors cannot be installed, or where workover (well start-up) is carried out on cluster pads of fields having a waterproofing layer, reinforced concrete structures may be used as anchors, subject to agreement with the organisation operating the hazardous production facility and provided that the above calculations and tests are carried out. All anchors and guy lines shall be marked with clearly visible identification signs (red flags or warning tape). Anchors shall have a guard preventing vehicles from driving into them. When the workover unit (rig) is replaced, and in the case of prolonged workover (more than 2 months), each anchor shall be re-tested.
1235. The commissioning of the installed unit and equipment for operation is carried out by a commission, the composition and working procedure of which is established by the operating organisation.
1236. At well clusters with any type of base (log-mat, filled, hydraulic-fill or other) having oil and gas pipelines laid on the ground surface, well workover is carried out subject to their disconnection on the well side and at the metering device, and to the release of excess pressure.
1237. When working at well clusters equipped with centrifugal pumps, electric cables located within the area of movement and installation of equipment of workover crews and start-up crews shall be de-energised, removed from trestles (racks) and covered with guards ensuring the integrity of the insulation and the safety of workers. Wells are started up for operation upon completion of the movement and installation of equipment.
1238. Before the installation of equipment, where provided for by the plan, the well is killed with fluid and a report is drawn up. The type, density and quantity of the fluid, and the frequency of killing, are determined by the customer and set out in the work plan.
1239. Before workover operations begin, the functioning of the installed measuring instruments shall be checked.
1240. All technical devices used in explosion-hazardous areas shall be of explosion-proof design and equipped with emergency light and sound alarms and a lighting system.
1241. The load capacity of the workover unit (rig), derrick, mast, and the permissible wind load shall correspond to the maximum loads expected during workover. Workover units (rigs) shall be mechanised and equipped with an independent control panel for tripping operations and with measuring instruments, including a weight indicator recording the load on the hook. All process operations at the well shall be carried out from the unit's control panel, ensuring that the mast, drawworks and wellhead remain visible while they are performed. Derricks and masts of the units shall be secured with steel-wire-rope guy lines. The number, diameter and attachment points of the guy lines shall correspond to the unit's technical documentation. The unit shall be equipped with spark arresters and an emergency engine shutdown system. The unit's mast shall have a fitting for suspending the ESP cable roller. The roller shall be secured with a wire rope 8-10 mm in diameter. A plate shall be fixed to the mast in a conspicuous place. The plate shall indicate: the date of manufacture; the manufacturer; the unit's serial number; the (rated) load capacity of the mast; and the date of the unit's next technical inspection. The technical condition of workover units, including the inspection and testing of masts, shall be assessed within the time limits and in accordance with the requirements of regulatory technical documents.
1242. Workover units (rigs) with a load capacity exceeding 40 t shall meet the following additional requirements: the drawworks drive transmission shall be provided with a hook-load limiter; the unit shall have an automatic travelling-block height limiter with interlocking of drawworks drum movement (a travelling-block anti-collision device under the crown block); the unit shall have instruments enabling the chassis to be set to a horizontal position; the unit shall have a device for securing the travelling block and protecting the mast from damage during movement; the mast-raising system shall have remote control and shall ensure safety in the event of failure of hydraulic equipment components; noise levels at permanent workstations shall not exceed the maximum permissible levels; the unit shall be equipped with an emergency engine shutdown device; the unit shall be equipped with everything necessary for lighting the workstations, a 24 V DC rectifier transformer, a device for recharging batteries and a 24 V DC circuit for emergency lighting; the unit shall be equipped with a ladder fitted with a device for the safe ascent of the derrickman and a device for his emergency evacuation; the unit shall be equipped with hydraulic support jacks with mechanical locks and foundation beams for them; the unit, where provided for by its design, shall be equipped with a working platform enclosure 2.5 m in height with single doors on each side of the platform and a double-leaf door on the working platform side. The derrickman's working platform enclosure shall be made using durable, dense material; the crown block shall have 1 sheave for a 13 mm diameter rope of the auxiliary drawworks, two sheaves for a rope not less than 10 mm in diameter for suspending power tongs and a fitting for suspending the hydraulic tong; the unit shall have audible and visual signalling of the extension and retraction of the second mast section; the unit's pneumatic system shall be equipped with an air dryer; the unit, where provided for by the technical specification for its development and manufacture, shall ensure the possibility of vertical stabbing of pipe and shall include a set of equipment and tools for working with tubing, drill pipe 60, 73 and 89 mm in diameter and sucker rods 19, 22 and 25 mm in diameter when they are set back in the fingerboard.
1243. Mobile pumping units intended for work at wells shall be provided with shut-off and safety devices and shall have instruments monitoring the main process parameters, displayed at the control panel.
1244. Coiled tubing units with continuous flexible tubing shall be equipped and fitted with the following instrumentation systems for monitoring and recording: loads arising during tripping operations; running depth; the flexible tubing's service life; pressure when pumping fluids through the flexible tubing during process operations; wellhead pressure; flushing fluid flow rate; combined real-time monitoring of loads and pressures; and automatic shutdown of the drive in the event that permissible loads are exceeded. Coiled tubing units with flexible tubing shall be equipped with a set of wellhead devices for running tubing under pressure, rated for the maximum possible wellhead pressure.
1245. The preparation of the site, the installation and operation of coiled tubing units, and the monitoring of tubing wall thinning, shall be carried out in accordance with the technical specifications and the manufacturer's operating instructions.
1246. Well workover units are positioned on the wellsite pad and centred relative to the wellhead in accordance with the manufacturer's operating instructions.
1247. Before workover operations begin, the well shall be killed in accordance with the procedure established by the work plan. The type, density and quantity of the fluid, and the frequency of killing, are determined by the customer and set out in the work plan. All wells with a formation pressure above hydrostatic, and wells in which (according to the calculations performed) conditions for flowing or a kick are retained at formation pressures below hydrostatic, are subject to killing. Wells producing fluid containing hydrogen sulphide that creates a risk of stress corrosion cracking of the metal of casing, equipment and tubing strings shall be killed with a fluid containing a hydrogen sulphide neutraliser. Where hydrocarbon-based fluids are used as kill fluids, the necessary safety requirements shall be established in the kill instructions and the workover plan.
1248. Routine and major well workover may be carried out without prior killing at wells equipped with downhole safety valves and at fields with mining and geological conditions that preclude the spontaneous inflow of formation fluid to the wellhead. The list of such wells by field (or individual sections thereof) is approved by the organisation operating the hazardous production facility (the customer).
1249. Before dismantling the wellhead tree, the pressure in the tubing and annulus shall be reduced to atmospheric. A well equipped with a downhole safety valve, in which prior killing is not envisaged, shall be shut in, bled down to atmospheric pressure and held for not less than three hours, and flushed to bring any gas-cut slug of fluid to the surface. The wellhead tree is dismantled after the cessation of gas release from the well has been visually confirmed and the constancy of the fluid level in it has been checked.
1250. Tripping operations, and workover operations involving a load on the mast (derrick), shall be prohibited, regardless of well depth, without a serviceable weight indicator.
1251. Well workover using equipment and instruments run on wire lines and geophysical cables is carried out subject to the following conditions being ensured: preventive workover operations shall be carried out under plans approved by the organisation operating the hazardous production facility (the customer); safety-valve overhaul operations, and their frequency, are carried out in accordance with the requirements of the operating documentation.
1252. Tripping operations shall be prohibited in wind of 15 m/s or more, during heavy rain, heavy snowfall and fog with visibility of less than 50 m, and where the shift crew is incomplete. Where the unit's data sheet specifies a lower wind speed, the value in the data sheet shall be followed. The speed of running and pulling tubing and downhole equipment with a closed flow passage shall not exceed 0.25 m/s.
1253. Leaving the wellhead unsealed during breaks in work, regardless of their duration, shall be prohibited.
1254. Pipe is pulled from the well with make-up fluid added to maintain the safe static level in the well specified in the work plan. Where the difference between the volume of make-up fluid added and the metal volume of the pipe pulled exceeds 0.2 m3, pulling shall be stopped and measures taken to seal the wellhead. Before workover begins, the well shall be provided with a reserve of fluid of the appropriate density in the following quantity: not less than 4.5 m3 directly at the well in the make-up unit, and not less than two well volumes held at the well or at the fluid mixing unit.
1255. If a kick is detected, the wellhead shall be sealed, and the crew shall act in accordance with the emergency response plan developed in accordance with paragraph 6 of these Rules.
1256. Before the workover of a well equipped with an electric submersible centrifugal pump, the cable shall be de-energised. The winding and unwinding of the cable onto a drum installed in the same vertical plane as the cable roller and the wellhead shall be mechanised. Cable turns shall be laid onto the drum in regular rows.
1257. The drum with the submersible pump cable shall be within sight of the working platform. The presence of people between the wellhead and the drum during running (pulling) of the pump shall be prohibited.
1258. Bailing to clean sand plugs, asphaltene-resin, paraffin, gypsum and other deposits shall not be permitted in flowing wells, in wells with a possible kick, or in wells containing hydrogen sulphide.
1259. When carrying out repair and isolation work, perforation of casing strings shall be prohibited within the interval of possible formation fracturing by gas or oil pressure (after inflow has been induced), and within the interval of permeable non-productive formations.
1260. Before starting operations to sidetrack a lateral wellbore, all inter-formation flows in the annulus identified during well testing shall be eliminated.
1261. Before sidetracking a lateral wellbore, a cement plug shall be set in the casing string; the presence of the plug is verified by setting down drill string weight not exceeding the maximum permissible load on the set cement. In addition, the cement plug is tested by hydraulic pressure testing together with the casing string and the blowout preventer installed on it, to a pressure exceeding by not less than 10 per cent the possible pressure arising during the killing of kicks and open blowouts and during well testing and operation, but not higher than the permissible pressure-test rating of the production casing.
1262. The cutting of windows in casing strings shall be carried out using special technical means (casing cutters, whipstocks and other specialised equipment).
1263. The spatial position of the lateral wellbore shall preclude any harmful effect on other wells of the field (producing, suspended or abandoned) located close to the designed trajectory of the well's lateral wellbore.
1264. Well start-up after the completion of workover operations shall be carried out with the participation of a representative of the customer.
1265. During well start-up and workover, measures shall be taken to prevent the spillage of oil and of fluid present in the wellbore. Where it is necessary to pull tubing (drill pipe) with a siphon (the valve not removed, "sludging" of the tubing string, or other possible causes), the well shall be continuously topped up, maintaining the fluid level at the wellhead specified in the work plan. At the wellheads of wells in which the pressure in productive formations exceeds the hydrostatic pressure generated by the formation fluid when the wellbore is filled to the wellhead, preventer stacks or complete sealing devices shall be installed.
1266. For the duration of perforating and blasting operations, a hazard zone with a radius of not less than 10 m is established around the wellhead.
1267. Well workover on a cluster pad without shutting in the adjacent well is permitted, subject to the actions and technical means provided for by the plan being carried out and used. Start-up, workover and well commissioning operations may be carried out simultaneously with drilling on the cluster, and workover crews may work simultaneously. Under such conditions, each performing authority shall immediately notify the other parties working on the cluster of the occurrence of an abnormal situation in its area (for example, signs of a kick or a deviation from the technological regulations). In such cases, all work on the cluster is suspended until the causes of the abnormal situation have been eliminated. The procedure for the simultaneous conduct of operations on the cluster is agreed with the professional emergency rescue service and approved by the organisation operating the hazardous production facility (the customer).
1268. During the workover of wells at gas-lift clusters, before equipment is positioned, the injection of gas into the well being worked over, and into the adjacent wells on the left and right (for the period of positioning), is stopped. Excess gas pressure in the gas pipelines and the wellhead piping is bled down to atmospheric. The installation of equipment and special vehicles on operating gas flow lines shall be prohibited. During the workover of mechanised wells on a cluster with a distance of 1.5 m or less between wellhead centres, adjacent wells shall be shut in and, where necessary, killed.
1269. During major workover or start-up of wells, the wells adjacent to the well being worked over (one on the left and one on the right) that are under pressure are closed off with a shielding device ensuring the protection of the wellhead equipment from mechanical damage by falling objects. The need to install shielding devices is determined by the well workover plan.
1270. Wells adjacent to the well being worked over that are operated with sucker-rod pumps may be shut in or may continue to operate subject to the appropriate precautions determined by the work plan.
1271. The design of the shielding device or barrier shall: preclude the formation of unventilated zones; ensure free access to the control units of the well's wellhead tree.
1272. When a gas-lift well is handed over for routine or major workover, in addition to the well workover plan, a layout diagram of the gas and oil pipeline communications and piping of all wells of the cluster shall be provided, showing dimensions and the procedure for shutting off gas-injection wells.
1273. The shutting off of gas pipelines and the dismantling of the gas piping of the gas-lift well being handed over for workover is carried out by the customer's service (the subdivision operating the wells).
1274. Before equipment is positioned for downhole or major workover of wells, the injection of gas into the well being worked over and into one well on the left and one on the right is stopped. Excess gas pressure in the pipelines and piping is bled down to atmospheric. After the equipment has been positioned and the workover unit installed, one well on the left and one on the right are put into operation. Before the equipment and the workover unit are dismantled (workover completed), one well on the left and one on the right are shut in and the excess pressure is bled down. All work to shut in producing wells and put them into operation is carried out by the customer's relevant services.
1275. Requirements for the installation and operation of the blowout preventer during well workover operations are determined by the operating manual, the manufacturer's instructions, and the plans and work programmes.
1276. The expediency and feasibility of using previously abandoned wells by reconstructing them are established by a commission set up by the organisation operating the hazardous production facility.
1277. The basis for the decision is the results of a preliminary survey of the well's condition and an assessment of the reliability of the part of its casing used during further operation.
1278. Before starting well reconstruction operations, including survey operations, the wellhead shall be fitted with a blowout preventer in accordance with Chapter XXIII of these Rules. The wellhead, together with the blowout preventer, shall be pressure-tested to a pressure exceeding by not less than 10 per cent the possible pressure arising during the killing of kicks and open blowouts and during well testing and operation, but not higher than the permissible pressure-test rating of the production casing.
1279. The choice of equipment, the level of its fitting-out with technical means, and its provision with instrumentation are established by the design documentation with regard to the nature and types of the planned work and operations, taking safety into account.
1280. The acceptance for operation of a reconstructed well is carried out in accordance with the procedure established by the customer for the acceptance of newly drilled wells.
1281. Geophysical operations shall be carried out in the scope and with the frequency provided for by the geological and technical work order for drilling operations, the plan for repair and restoration operations, and the arrangements for monitoring the development of formations and the condition and operation of wells and downhole equipment.
1282. Geophysical operations shall be carried out after special preparation of the site and the wellbore, ensuring the convenient and safe operation of surface equipment and the unobstructed running (pulling) of downhole instruments and tools on the cable to the survey interval or to the bottom of the well. The readiness of the site and the well for geophysical operations is confirmed by a bilateral report.
1283. Before carrying out operations using sources of ionising radiation, the wellbore shall be gauged with a downhole instrument without the source, or with a gauge having weight and dimensional characteristics corresponding to that instrument.
1284. Geophysical operations shall be carried out in the presence of a representative of the organisation under whose authority the well is placed. The customer's workers and equipment may be engaged in geophysical operations where this is necessary for carrying out the survey technology.
1285. Overall direction of the operations, including where the customer's workers are engaged in geophysical operations, is entrusted to a representative of the geophysical organisation. Workers so engaged shall receive instruction on the safe conduct of the work.
1286. Geophysical organisations whose activities are connected with the development of oil, gas and gas condensate fields shall be guided by the requirements and provisions of these Rules and by the safety requirements for blasting operations established by federal norms and rules in the field of industrial safety.
1287. Geophysical operations in oil and gas wells shall be carried out using equipment, cable and instruments whose technical characteristics correspond to the geological and technical conditions of drilling and operation of the wells.
1288. Logging units shall be equipped with: suspension and guide sheaves, stop shoes and a device for cutting the cable; means for visually monitoring the depth of cable running and pulling, and its travel speed and tension; connecting cables with durable electrical insulation coating; and an automated cable spooling device.
1289. For geophysical operations in wells under pressure, the set of surface equipment shall include lubricator devices tested for the pressure expected at the wellhead. Hydraulic testing of lubricators for working pressure shall be carried out not less than once every 6 months at the production service base, with a report drawn up.
1290. Equipment, cable and instruments having documents confirming that they have undergone the conformity assessment procedure, and measuring instruments and technical devices with measuring functions meeting the requirements of Federal Law No. 102-FZ of 26 June 2008 "On Ensuring the Uniformity of Measurements" (Collection of Legislation of the Russian Federation, 2008, No. 26, Art. 3021; 2021, No. 24, Art. 4188), may be used in geophysical operations.
1291. Prototype and experimental samples of geophysical equipment may be used only where permission has been given by the organisation under whose authority the well is placed.
1292. When geophysical instruments are run into the well, provision shall be made for assembling strings of integrated or combined multi-parameter instruments and for their connection to standardised cable heads. The design of the cable head shall ensure that it can be caught during fishing operations.
1293. The strength of the attachment of the instrument to the cable by means of cable heads shall be lower than the breaking strength of the corresponding type of cable.
1294. Cable used in geophysical operations shall have no defects in its armour. The condition of the armour shall be checked periodically, and after operations in aggressive media the cable shall be tested for breaking strength.
1295. Initiating devices shall be installed in a perforating or blasting apparatus only directly at the wellhead before the apparatus is run in. Initiating devices may be installed in a perforating (blasting) apparatus in the laboratory of a perforating station (mobile charging workshop) where an interlocking device precluding accidental actuation of the perforating and blasting apparatus is used, and in cases where initiating devices protected against the effects of stray currents are used. When installing electrical initiating devices in the perforating and blasting apparatus, accidental contact of the initiating device conductors with surrounding metal objects shall not be permitted.
1296. The geological and technical survey station shall be positioned in accordance with the standard layout for its connection to the drilling rig. Connecting cables and the gas-air line shall be suspended on supports or placed in protective fittings.
1297. The section of the flow line system where the degasser and the sensors monitoring the flushing fluid parameters are installed shall be illuminated during hours of darkness.
1298. Members of the drilling crew shall undergo instruction on methods of safe work with geophysical equipment and on interaction during the conduct of geological and technological surveys.
1299. The drilling foreman (driller) shall inform the head of the survey party (crew) of any deviations from the designed drilling process regime and the physico-chemical composition of the flushing fluid. Gas logging shall not be carried out where oil is added to the drilling fluid.
1300. On completion of drilling, before well logging, circulation shall be continued until the bottomhole portion of the flushing fluid reaches the surface.
1301. Before well logging begins, the well shall be prepared in such a way as to ensure the free passage of downhole instruments through its wellbore, without sticking or dragging during running and pulling.
1302. The head of the survey party (crew) shall promptly inform the drilling foreman (driller), who shall record in the drilling log the possibility of a complication or emergency situation arising.
1303. When logging a drilled wellbore, the hoist and the laboratory shall be positioned so as to ensure a good view of the wellhead, unobstructed passage of workers to the catwalk, and signal communication between them and the wellhead.
1304. The suspension sheave shall be securely fastened to the drilling rig's travelling system and raised above the wellhead to a height ensuring that the cable with instruments is run into the well along its axis.
1305. Before geophysical operations begin, the serviceability of the logging unit's braking system, the cable spooling device, the protective barriers, and the integrity of the earthing conductor and connecting cables shall be checked. Geophysical operations shall not be permitted where the drilling rig's auxiliary lifting mechanisms are faulty.
1306. The running and pulling of cable shall be carried out with monitoring of depth and tension, and at the speeds recommended for the corresponding types of instruments and tools.
1307. When testing wells with a wireline formation tester (OPK), and during hydrodynamic surveys, preparation for running the wireline formation tester shall be carried out on the rig catwalk on special supports. The depressurisation of wireline formation tester samplers at the well is permitted only using special devices ensuring the safety of the workers performing this work.
1308. Well logging in a cased wellbore shall provide information on the ability of the annular cement sheath to preclude inter-formation flow and the escape of fluid to the surface.
1309. Well logging during the operation of wells is carried out in accordance with geological and technical action plans.
1310. When running and pulling downhole instruments through a tubing string, the bottom of the string shall be fitted with a guide funnel.
1311. In vertical wells operated by pumping, with an eccentric tubing hanger, the clearance between the production casing and the tubing shall ensure the unobstructed passage of the downhole instrument to the survey interval.
1312. The guide roller shall be mounted so that its axis of rotation is parallel to the axis of the drawworks and the plane of rotation of the roller passes through the middle of the drawworks drum. All elements of the wellhead sealing equipment shall be clearly visible from the workstation of the logging unit operator.
1313. During surveys in injection wells, pressure may be bled briefly to run and pull instruments. Waste water used as the working agent shall be discharged to a specially prepared receiver.
1314. During surveys in producing wells, fluid seeping through the cable stuffing box shall be discharged into a tank installed near the wellhead.
1315. Wells with high wellhead pressure shall be surveyed using lubricator equipment. The installation and operation of this equipment shall be carried out with a special lifting unit made available to the geophysical survey party (crew).
1316. The surveying of wells during their start-up after drilling and major workover shall be carried out both before and after they are brought to the working operating regime.
1317. In all cases of surveying a well through tubing and through the annulus, the speed of pulling the cable shall be reduced when approaching the tubing guide funnel, the downhole pump and the wellhead.
1318. Workers of the geophysical survey party (crew) shall not be permitted to operate the master (shut-off) valve of the christmas tree while the geophysical cable is in the well, except in cases involving a threat of a kick. Valves shall be opened and closed slowly, avoiding water hammer when the pressure changes.
1319. Operations using geophysical methods to stimulate the bottomhole formation zone, both while the well is in its working regime and while it is undergoing major workover, shall be carried out under work plans.
1320. Perforating and blasting operations in wells shall be carried out in accordance with the technical project for perforating and blasting operations.
1321. The technical project for perforating and blasting operations is developed by the geophysical organisation and agreed with the drilling organisation and the organisation operating the hazardous production facility.
1322. When perforation and blasting operations are carried out as part of complex well testing and development technologies requiring direct interaction between the contractor's and the customer's workers, the work shall be carried out under plans approved by their managers.
1323. The head of the unit performing perforation and blasting operations (the head of the party or crew) shall hold the right to exercise responsible supervision of blasting operations. The person in charge of blasting operations carried out using electric initiation shall undergo electrical safety training and be assigned an electrical safety qualification group of not lower than III.
1324. Only blasters may carry out direct work with explosive materials. Certain operations involving perforation-blasting equipment that are not connected with handling initiation devices, assembling and checking the electric blasting circuit, or handling misfired perforation-blasting equipment, may be carried out by instructed workers of geophysical organisations under the direct supervision of a blaster or the person in charge of blasting operations.
1325. Workers servicing non-geophysical equipment who are engaged to carry out tripping operations and to activate devices run on tubing or drill pipe shall be instructed by the person in charge of blasting operations on safety measures and shall work under that person's supervision.
1326. Geophysical organisations shall have operating documentation for all perforation-blasting equipment, articles made of explosive substances and blasting instruments they use, and shall be guided by it at all stages of handling such items.
1327. The conditions for using perforation-blasting equipment in wells (maximum temperature and hydrostatic pressure, minimum through-bore diameter and other parameters) shall strictly comply with those permitted by the operating documentation for the specific perforation-blasting equipment. In wells where the temperature and pressure in the perforation (stimulation) interval are at a level within +/- 10 per cent of the maximum permissible values for the equipment used, measurement of these parameters before running the perforation-blasting equipment is mandatory.
1328. Perforation and blasting operations on a well may be commenced only after the work to prepare its site, wellbore and equipment for such operations has been completed and confirmed by a Well Readiness Certificate for Perforation and Blasting Operations.
1329. When perforation and blasting operations are carried out, the wellhead shall be equipped with shut-off valves and lubricator devices ensuring wellhead sealing during running, actuation and retrieval of the perforation-blasting equipment. When perforation and blasting operations are carried out in the course of well workover with a formation pressure exceeding hydrostatic pressure, the wellhead shall be equipped with blowout prevention equipment (BOP). The installation and hook-up diagram of this equipment shall be agreed with the professional emergency rescue service. The need to install BOP shall be indicated in the plan of work for well workover. Perforation and blasting operations may be carried out in wells under workover without installing BOP at the wellhead where: the formation pressure of the oil-bearing formation being opened (opened) excludes the possibility of spontaneous inflow of oil from the formation into the well, and there are no behind-casing crossflows in all overlying zones; blasting operations (for example, disconnection from stuck equipment) are carried out where there is a cement plug in the casing string covering the productive horizons.
1330. Control gauging of the wellbore shall be carried out by running a gauge on a cable, the diameter, weight and length of which shall correspond to the dimensional and weight specifications of the perforation-blasting equipment used. Where non-rigid perforation-blasting equipment is used (casingless perforators, powder pressure generators, cord torpedoes and other types of equipment), no restrictions are placed on the gauge length.
1331. Irrespective of the presence of electrical installations, all metal structures of the well shall have a reliable metallic bond with one another and shall be earthed to a single earth electrode (the well earthing loop).
1332. Sites for work involving the assembly and charging of perforation-blasting equipment shall be prepared at the well. These sites shall be located not less than 100 m from residential and domestic premises and not less than 50 m from the wellhead. Where perforation-blasting equipment is charged in the laboratory of a perforating unit, the distance shall be not less than 20 m from the wellhead. Where it is not possible to ensure the distances specified, the location of the site shall be selected with regard to minimum risk, substantiated, and indicated in the design for the perforation and blasting operations.
1333. Signs marking the boundaries of the hazardous zones of blasting operations shall be placed around the locations of work with explosive materials and perforation-blasting equipment: at locations for assembling perforation-blasting equipment - within a radius of not less than 20 m; at the wellhead - within a radius of not less than 50 m.
1334. For connecting individual earthing conductors of geophysical equipment to the well earthing loop or to the well's metal structures, the connection point shall be marked in an easily accessible, clearly visible location with an "Earth" sign.
1335. Where the electric method of blasting is used, measures shall be taken to protect against stray currents. In special cases, where it is not possible to implement such measures, work with initiation devices and the assembly of the electric blasting circuit shall be carried out in compliance with special measures developed by geophysical organisations and set out in the technical design for the perforation and blasting operations. In doing so, priority shall be given to the use of technical means of protection against stray currents - protected electric blasting systems, interlocks and other equipment.
1336. Verification of the serviceability of the fully assembled electric blasting circuit shall be carried out by measuring its resistance after the device has been run to a depth of not less than 50 m. Thereafter, the radius of the hazardous zone around the wellhead may be reduced on the instructions of the person in charge of blasting operations.
1337. When retrieving activated perforation-blasting equipment, in the absence of instrumental monitoring of the fact and completeness of detonation, the hazardous zone regime around the wellhead shall be maintained until the perforation-blasting equipment has been inspected by the blaster.
1338. Complications arising during geophysical operations in connection with sticking of the cable, downhole instrument or load are eliminated under the direction of the person responsible for carrying out the geophysical work, with the participation of drilling crew workers.
1339. Where it is not possible to eliminate sticking by working the cable, a report shall be drawn up and the technical management of the organisation in charge of the well, as well as of the geophysical organisation, shall be notified.
1340. Accidents are eliminated in accordance with a plan drawn up jointly by the customer organisation, the drilling contractor and the geophysical operations contractor, using the technical means of both parties.
1341. Before running into the well, sketches shall be prepared for all non-standard assemblies of working and fishing tools.
1342. To retrieve an instrument, device or load from the well, a fishing tool corresponding to the design of the protective cap of the cable socket shall be used. Where the cable is left in the well, drilling it out may be permitted only after all other possible methods of retrieving it have failed to produce a result and further fishing operations are impracticable.
1343. Where it is not possible to retrieve an instrument with a radioactive source from the well, the source shall, in agreement with the sanitary and epidemiological supervision authorities, be knocked down to the bottom and cemented in. Further operations to drill the wellbore shall be carried out under dosimetric monitoring of the drilling fluid.
1344. The territorial authority of Rostechnadzor shall be notified immediately of all cases where perforation-blasting equipment containing explosive materials is left in the well.
1345. Perforation-blasting equipment retrieved from the well that is not subject to disarming owing to deformation of the housing shall be returned to the explosive materials warehouse in compliance with the safety measures provided for in the operating documentation.
1346. Where signs of a kick (gas, oil or water influx) appear, the wellhead shall be sealed in accordance with the accident localisation and elimination action plan.
1347. Field geophysical operations in wells are carried out in the presence of representatives of the operating organisation and the drilling contractor organisation, under the direction of a responsible worker appointed by order of the organisation carrying out the field geophysical operations.
1348. Before field geophysical operations are carried out, the insulation of the electrical equipment and the serviceability of the protective earthing device of the drilling rig or well are checked. A metallic bond between the well's earthing devices and the power source to which the geophysical current-consuming devices are connected is mandatory.
1349. Before work in the well begins, the operating organisation, jointly with the drilling contractor organisation, draws up a certificate of well readiness for field geophysical operations, which is signed by the responsible representative of the drilling contractor organisation and by the operating organisation. Work in the well shall not be permitted to commence before the certificate of well readiness for field geophysical operations has been executed.
1350. The organisation operating the fixed offshore platform, floating drilling unit, offshore trestle and platform technological complex is responsible for: preparing the well for geophysical operations; providing working areas or premises on the fixed offshore platform, floating drilling unit, drilling vessel, offshore trestle and platform technological complex for the placement of geophysical instruments and equipment; allocating and equipping locations on the fixed offshore platform, floating drilling unit, offshore trestle and platform technological complex for the storage of explosive materials.
1351. To carry out geophysical operations, the operating organisation: ensures the mechanisation of loading and unloading operations at the hazardous production facility of the offshore oil and gas complex and in ports for vessels delivering cargo of the geophysical organisation sent to and from the hazardous production facility of the offshore oil and gas complex; ensures the timely and safe transportation of workers of the geophysical organisation by vessel from the port to the fixed offshore platform, floating drilling unit, offshore trestle, platform technological complex and back, including the embarkation and disembarkation of persons at the fixed offshore platform, floating drilling unit, offshore trestle, platform technological complex and the delivery vessel; provides rest premises for workers; allocates rescue equipment to workers of the geophysical organisation while they are on the fixed offshore platform, floating drilling unit, offshore trestle or platform technological complex.
1352. The geophysical organisation is responsible for the safe conduct of field geophysical operations on the fixed offshore platform, floating drilling unit, offshore trestle, platform technological complex and for the storage of explosive materials.
1353. Field geophysical operations shall not be permitted in wells during a kick or lost circulation.
1354. The logging hoist is installed so that the axis of the drum is perpendicular to the plane passing through the middle of the drum and the wellhead, and so that direct visibility of the cable along its entire length from the hoist to the rotary table of the drilling rig or to the wellhead is ensured from the logging winch cabin.
1355. During field geophysical operations, two-way communication is provided between operators located in the laboratory premises, at the winch control panel and at the wellhead.
1356. Before perforating the well, the tightness of the wellhead assembly of all wells on the fixed offshore platform, floating drilling unit, offshore trestle or platform technological complex is checked. Any leaks detected are eliminated and a certificate of well readiness for perforation is drawn up.
1357. Before perforation and blasting operations are carried out, the well is filled with drilling mud of the required parameters, control is ensured over its level to maintain hydrostatic pressure balance in relation to the formations being opened, and the wellhead is equipped with blowout prevention equipment (BOP) and a lubricator.
1358. Explosive materials are delivered to the hazardous production facility of the offshore oil and gas complex immediately before perforation and blasting operations, in the quantity necessary to carry out the work. On completion of the perforation and blasting operations, unused explosive materials are removed from the fixed offshore platform, floating drilling unit, offshore trestle or platform technological complex.
1359. Explosive materials for perforation and blasting operations are placed in portable containers installed at locations specially designated for this purpose on the fixed offshore platform, floating drilling unit or offshore trestle. Locations for storing explosive materials are equipped with a device for jettisoning the containers into the sea in emergency situations. The container is fitted with a security alarm and a reliable locking device, the key to which is held by the person responsible for carrying out the perforation and blasting operations and for the safekeeping of the explosive materials, who is present on the fixed offshore platform, floating drilling unit or offshore trestle.
1360. Perforation and blasting operations at the hazardous production facility of the offshore oil and gas complex are carried out under a plan for the safe conduct of work approved by the operating organisation, calculated so as to ensure that the running of the perforator or torpedo into the well and the first actual firing of the perforator or detonation of the torpedo take place during daylight hours. This work may be permitted after nightfall provided sufficient lighting is ensured for the work locations and the hazardous zone. The lighting shall be prepared and checked before the perforation and blasting operations begin, in accordance with the plan referred to above.
1361. Before perforation and blasting operations, the housings of the logging laboratory and the logging hoist are connected to the earthing loop of the hazardous production facility of the offshore oil and gas complex.
1362. For the period of perforation and blasting operations on the fixed offshore platform, floating drilling unit or offshore trestle, a hazardous zone is designated, within which the following are located: the drilling derrick, the route of the logging cable, the location for charging perforation-blasting equipment and preparing torpedoes, and the logging winch.
1363. The composition of the workers of the geophysical party and the drilling crew present within the hazardous zone during perforation and blasting operations is established jointly by the responsible representatives of the operating organisation, the drilling contractor organisation and the organisation carrying out the perforation and blasting operations. All other persons shall be removed from the hazardous zone for the duration of the perforation and blasting operations.
1364. Before perforation and blasting operations, the following shall be done: notice shall be given over the public address system of the commencement of the perforation and blasting operations and of the prohibition on the presence of unauthorised persons in the hazardous zone; radio stations that are in contact shall be notified of the suspension of radio station operation on the fixed offshore platform, floating drilling unit or offshore trestle until special permission is given; mobile (portable) internal communication radio stations shall be switched off; hot work shall be stopped; loading and unloading operations shall be stopped; active cathodic protection shall be switched off.
1365. During perforation and blasting operations, the fire-fighting equipment of the hazardous production facility of the offshore oil and gas complex is kept ready for immediate use.
1366. During perforation and blasting operations, an emergency rescue vessel equipped for eliminating oil and oil product spills remains at a distance permitting it to begin containing possible oil spills immediately.
1367. Misfired perforation-blasting equipment, as well as a torpedo with non-retrievable blasting devices, is transported by sea to shore for subsequent destruction where destruction on site is not possible. In doing so, the conductors connected to the blasting devices are short-circuited. The action plan for transporting the misfired equipment (torpedo) is developed by the organisation carrying out the perforation and blasting operations and agreed with the operating organisation before work begins.
1368. Perforation and blasting operations may be carried out only using a perforation-blasting equipment interlock device.
1369. Perforation and blasting operations shall not be permitted in wells during a thunderstorm.
1370. These requirements apply to organisations whose activities relate to the design, exploration, development and production of oil, gas and gas condensate fields whose output contains more than 6 per cent (by volume) of hydrogen sulphide.
1371. For all hazardous production facilities associated with the development of such fields and containing sources of possible emissions and leaks of harmful substances and mixtures into the atmosphere, a buffer (protective) zone shall be established.
1372. Every hazardous production facility shall have an accident localisation and elimination action plan, and organisations carrying out work at the field shall have a plan for joint action in the event of emergency situations.
1373. The organisation of the protection of the hazardous production facility and of the access control regime for its territory is determined by the design documentation on the basis of applicable regulatory legal acts.
1374. The arrangement of perimeter protection and the location of checkpoints, as well as their layout, shall ensure the possibility of prompt emergency evacuation of workers in various wind directions.
1375. All vehicles may be admitted to the territory of explosion- and fire-hazardous facilities only where fitted with a spark arrester, and special equipment transporting flammable liquids shall additionally be fitted with devices for discharging static electricity.
1376. The bringing onto the territory of facilities of toxic or fire-hazardous substances not used at the given facility, as well as of hazardous substances used there in quantities exceeding the established standards for simultaneous storage, shall be prohibited.
1377. Explosion- and fire-hazardous facilities without the permanent presence of workers (for example, well sites) shall be fenced and fitted with the relevant safety signs and warning notices. Such facilities, as well as remote areas of production facilities with permanent personnel and communication routes, shall be monitored by means of scheduled inspections and surveys.
1378. Workers admitted to the territory of the facility shall be: provided with personal protective equipment and isolating respiratory protective equipment and with automatic gas detectors; instructed, against signature, on the rules for the safe conduct of work and presence in the working area.
1379. Work involving opening the productive formation, perforation, well flow inducement, hydrodynamic surveys and other operations associated with the possibility of hydrogen sulphide appearing in the air environment shall be carried out under a plan, under the direction of a responsible worker appointed by the organisation's technical manager.
1380. The design documentation for field development shall provide for the principal organisational and technical solutions for ensuring the gas safety of workers and of the population living in the zone of possible gas contamination, in emergency situations.
1381. The design documentation for field development shall provide for the locations of safe places, of collective protective equipment for workers and the population, of environmental gas contamination monitoring stations, gas safety posts, wind cones and checkpoints.
1382. Design solutions shall provide for the rational use of natural resources, the exclusion of the possibility of irreversible man-induced changes to the natural environment, including in the event of possible emergency releases of harmful substances, substantiation of the assessment of the reliability and accident-free operation of production processes and equipment, an assessment of the risk of occurrence and of the possible consequences of predicted emergency situations associated with the release of harmful substances, as well as solutions aimed at preventing, containing and eliminating accidents and protecting workers and the population from hazardous production factors.
1383. The design documentation for field development shall include, in full, calculations and substantiation of the dimensions of the buffer zone, precluding the possibility of exceeding, at its boundaries, the threshold toxic dose values of harmful substances in the surface layer of atmospheric air under unfavourable meteorological conditions. The calculations and substantiation of the buffer zone shall be carried out with regard to the maximum (in terms of volume and duration) predicted emergency releases of harmful substances. Within the territory of the buffer zone, the following shall be prohibited: residence of the population (under the rotational work method, workers at the field may be permitted to reside in rotational settlements located within the buffer zone, provided that all design solutions for field development are implemented); the operation of sports facilities, pre-school, school, medical and health-improvement institutions, recreation areas and other places of mass public gathering; the construction of production facilities and other facilities not connected with field development; the stopping and parking of transit passenger rail transport and of any road transport on public roads; the presence of persons without respiratory protective equipment who have not undergone the relevant training in the use of respiratory protective equipment or instruction on the rules for safe presence in the buffer zone. The design documentation shall define the fundamental solutions for organising the buffer zone, the access control regime, the procedure for the safe presence of people and the conduct of work, and shall provide for actions and means for relocating settlements, facilities and places of mass public gathering, for the engineering arrangement of the buffer zone boundary with checkpoints and special information signs. These solutions shall be defined with regard to the development of work to bring new sections of the field into production. The boundary of the buffer zone is shown on cartographic materials forming part of the design documentation for field development (connection of additional wells). The boundary of the buffer zone is marked on the ground by the organisation for whose hazardous production facility it has been established. Any change in the location of the buffer zone boundary on the ground is carried out in accordance with the design documentation as new sections of the field are brought into production. The organisation for whose facilities the buffer zone has been established informs the population, systematically (once a year) and as the location of its boundary changes on the ground, through the mass media of the intended purpose of the buffer zone, its boundaries, the access control regime, the procedure for safe presence, and other conditions and restrictions defined by the design solutions.
1384. For each of the principal organisational and technical solutions aimed at ensuring the gas safety of workers and the population for the period of possible emergency releases, the design documentation shall substantiate and define the specific types and quantities of instruments, materials and equipment required, as well as the locations (structures) for their storage and preparation for use.
1385. Where more than 6 per cent (by volume) of hydrogen sulphide is detected in the formation fluid of the first exploratory well, which was not provided for by the working design for drilling the well, further drilling of the well shall be carried out in compliance with the requirements of Chapters L - I of these Rules.
1386. The design documentation for field development shall set out: well designs, the diameters and setting depths of production and tubing strings; requirements for the inhibitor protection of equipment and pipes; the principal solutions for the safe use of subsoil; requirements for the use of associated products (hydrogen sulphide, condensate, helium and other possible gases).
1387. The working design for drilling wells shall specify: the conditions for calculating casing and tubing (production) strings based on the threshold stress of pipe steels, taken as not exceeding 0.75 of the yield strength; the methods and frequency of checking the wear and monitoring the corrosion condition of drill pipe, kelly, tubing and elements of pipe strings; the types of casing heads, the methods for testing and installing them (without the use of welded joints); the types of neutralisers, the methods and technology for neutralising hydrogen sulphide in the drilling mud, as well as the consumption of reagents for this purpose throughout the well drilling process; the methods for monitoring the content of hydrogen sulphide and the neutralising reagent in the drilling mud; the methods and means for ventilating the working area of the drilling site, the sub-derrick space and the drilling premises, including the pump unit premises and the drilling mud treatment premises; actions for protecting people and the environment during the processes of drilling, testing and development of the well; the methods and means for monitoring the content of hydrogen sulphide in the air of the working area; the technology for separating gas from the drilling mud with subsequent diversion for flaring; the types of inhibitors and the quantity required for well development and testing operations; actions for the prevention and early detection of a kick; the procedure for collecting and storing liquid products in closed vessels pending neutralisation and further disposal; the method for monitoring well filling during tripping out; the method for monitoring the mud displaced from the well during tripping in; cementing slurries resistant to the action of hydrogen sulphide, for cementing casing strings.
1388. To ensure the construction of the hazardous production facility, the subsoil user (customer): hands over to the contractor, for the performance of work, the design documentation approved by the customer and having passed state expert review, in electronic and paper form, in the composition necessary for the work to be carried out by the contractor and subcontractors; verifies that the performers of the work and the suppliers of equipment and materials hold the necessary permits. Where deviations from the design documentation, the use of non-designed materials, or violations of the procedure or quality of the work performed are detected, the customer (the customer's construction supervision) shall suspend the construction and installation work and issue an instruction to the performers of the work (the contractor) to remedy the violations detected.
1389. It shall be prohibited to develop the territories of mining allotments for oil, gas and gas condensate fields with a high content of hydrogen sulphide with production facilities and other facilities not connected with the extraction of oil, gas and gas condensate.
1390. Production facilities, gas-hazardous locations and gas and gas-condensate pipeline routes shall have indicators, notices and the necessary signs.
1391. Devices (for example, a cone or wind vane) for determining wind direction and indicators of the cardinal points shall be installed on the territory of drilling and industrial sites. During darkness, the devices shall be illuminated.
1392. The following shall be displayed in the premises of the control room and in the wagon-cabins: a process flow diagram (mnemonic diagram) of the layout of equipment and pipelines, showing the instrumentation and automation equipment, safety and shut-off control devices located on them, as well as diagrams of the installation of hydrogen sulphide sensors and the location of air monitoring points; a facility diagram showing the location of emergency stores, collection points, gas safety islands, the main and back-up routes for the movement of people and transport, the predominant directions of dispersion and the locations of possible accumulation of hydrogen sulphide in an emergency situation, and communication and warning equipment; a warning diagram showing the telephone numbers of the gas rescue service and other emergency services, the fire service and the medical unit; the operational part of the accident localisation and elimination action plan.
1393. The distance from the wellhead to the drilling pumps at fields with a volumetric hydrogen sulphide content exceeding 6 per cent shall be not less than 30 m. Open sections of the circulation system shall be located outside the pump-room premises.
1394. Premises of production facilities shall be equipped with permanently operating mechanically induced supply and exhaust ventilation, as well as an emergency ventilation system interlocked with air-monitoring instruments. In premises with periodic presence of workers, gas detectors and ventilation units with manual switching from outside the premises shall be installed.
1395. Crews and shifts working within the field shall be provided with reliable two-way telephone or radio communication (with continuous call capability) with the organisation's dispatcher, and those working directly at a gas-hazardous facility shall additionally be provided with telephone communication with the organisation's dispatcher and the transport organisation.
1396. Premises for preparing and taking meals, for shift rest, and the communications unit are located not less than 200 m from the wellhead.
1397. At installations, in premises and on industrial sites where hydrogen sulphide may be released into the air of the working area (drilling rig, producing well, oil and gas flow-rate measurement units and other equipment involved in the process), continuous monitoring of the air environment and signalling of hazardous concentrations of hydrogen sulphide shall be carried out.
1398. The locations for installing sensors of stationary automatic gas detectors are determined by the design documentation for field development, with regard to gas density, the parameters of the equipment used, its placement and the suppliers' recommendations.
1399. At drilling rigs, sensors shall be placed at the base of the derrick, at the rotary table, at the start of the flow-line system, at the shale shakers, in the pump room (2 units), at the receiving tanks (2 units) and in the office premises.
1400. Stationary gas detectors are installed at a height of not more than 50 cm above ground or floor level and shall have audible and visual signals with output to the dispatch point (control panel) and at the location of the sensors.
1401. Monitoring of the air environment in the populated locality shall be carried out at stationary points and by mobile laboratories in accordance with a schedule approved by the organisation's technical manager. The results of the analyses shall be entered: in the analysis registration log; in the sample card (recording the necessary sampling data: location, process, wind direction and speed, and other meteorological conditions), and shall also be transmitted as appropriate to interested organisations, including local authorities.
1402. Measurements of hydrogen sulphide concentration by gas analysers at the facility shall be carried out in accordance with the organisation's schedule, and, in emergency situations, by the gas rescue service, with the results of the measurements entered in a log.
1403. In addition to automatic monitoring, workers shall monitor the air environment using portable gas analysers: in premises where gases and liquids containing harmful substances are pumped - every four hours; in premises where the release and accumulation of harmful substances is possible, and at outdoor installations at locations of their possible release and accumulation - not less than once per shift; in premises with no sources of release but where harmful substances may enter from outside - not less than once per day; at locations of permanent presence of workers where there is no need to install stationary gas detectors - not less than twice per shift; at locations serviced periodically - before work begins and during the course of work; in the tank farm, at the centre of each tank group, and around the containment dyke at a distance of 5-10 m from it, on the axial lines of the tank on the leeward side - not less than once per shift; during emergency work in a gas-contaminated zone - not less than once every 30 minutes. After an emergency situation has been eliminated, in accordance with the accident localisation and elimination action plan, an additional analysis of the air shall be carried out at locations of possible accumulation of harmful substances.
1404. Before opening (50-100 metres before reaching the top of) formations containing fluids with hydrogen sulphide, and throughout the period of their opening, it is necessary to: install a geological and engineering monitoring station for drilling at fields with a hydrogen sulphide concentration of more than 6 per cent; install warning signs around the drilling rig site (on access routes, at points where entry to the drilling rig site is possible); check the serviceability of hydrogen sulphide monitoring devices in the working area air, and the availability and readiness of personal protective equipment (PPE); treat the drilling fluid with a neutraliser; check the condition of the blowout prevention (BOP) equipment; keep at the drilling rig a reserve of materials and chemical reagents, including hydrogen sulphide neutralisers, sufficient to treat the drilling fluid in a quantity of not less than two well volumes; at fields with a volumetric hydrogen sulphide content of more than 6 per cent, arrange round-the-clock standby of evacuation transport; ensure the availability of a cementing unit at the drilling rig and its constant readiness for operation; determine the routes for workers to leave the hazard area in emergency situations; members of the work team shall undergo induction on the emergency response plan (PMLA), be made familiar with the routes for leaving the hazard area, which shall be confirmed by their signatures in their individual induction record cards.
1405. The opening of formations containing hydrogen sulphide shall be carried out after verifying and establishing the readiness of the drilling rig and workers for the opening of the formation, and after verifying the implementation of actions to protect workers and the population in the zone of possible gas contamination in the event of an emergency release of oil and gas (open blowout), under the direction of the person responsible for carrying out the work. The verification shall be carried out by a commission of the drilling organisation chaired by a responsible person approved by the head of the organisation, with the participation of labour protection personnel and other workers. The results of the verification shall be documented in a report.
1406. When drilling formations containing hydrogen sulphide, the presence of hydrogen sulphide and sulphides in the drilling fluid shall be monitored. If they appear, the drilling fluid shall be additionally treated with a neutraliser.
1407. Drilling of productive horizons at facilities of fields falling under paragraph 1370 of these Rules shall be carried out with ball valves in a corrosion-resistant design installed above and below the kelly. A pressure-tested special pipe, matching the upper section of the drill string in diameter and strength characteristics, shall be kept on the rig catwalk. The pipe shall be painted yellow and fitted with a ball valve in the open position. A flare unit shall be included in the BOP manifold line.
1408. For the early detection of gas shows, monitoring shall be carried out of changes in: the level of drilling fluid in the well in the absence of circulation; the rate of penetration and pressure in the discharge line; the level of fluid in the receiving tanks; the gas content in the fluid, the sulphide content and the density of the drilling fluid.
1409. Well development operations are carried out with the mandatory presence of a representative of the organisation operating the hazardous production facility (the customer).
1410. Before carrying out the development and testing of oil, gas and gas condensate wells, a work plan shall be drawn up and approved by the technical managers of the organisation operating the hazardous production facility and of the organisation authorised to carry out this work. The work plan shall indicate the number of workers, the actions and means for ensuring their safety, including breathing apparatus, measures for accident prevention, the means and schedule for monitoring the hydrogen sulphide content in the working area air, and actions to be taken in the event the maximum permissible concentration (MPC) is exceeded. All workers involved in the development and testing of wells shall be made familiar with the plan. The work plan shall be accompanied by a diagram showing the layout of equipment, machinery and mechanisms, indicating the routes for leaving the hazard area in the event of a possible emergency and gas contamination for any wind direction, as well as a diagram showing the layout of facilities within the sanitary protection zone and nearby populated areas.
1411. The christmas tree shall be connected to blowdown lines directed in opposite directions. Each line shall be not less than 100 metres long (except for offshore oil and gas hazardous production facilities) and shall be connected to a flare unit with remote ignition. The types of threaded pipe connections for the lines shall correspond to the expected pressures, and shall be installed and pressure-tested for leak-tightness at 1.25 times the maximum pressure. The lines shall be secured to concrete or metal supports, with no bends or sagging permitted. The method of securing the line shall preclude the occurrence of local stresses.
1412. Kill lines for well killing through the tubing and annulus shall be connected to the christmas tree.
1413. Kill lines shall be fitted with check valves. For oil wells with a gas factor of less than 200 m3/t, the line length shall be not less than 50 metres. In all other cases (except for offshore oil and gas hazardous production facilities), the length of the kill line shall be not less than 100 metres.
1414. The safety valve of the unit (rupture disc) shall be connected by an individual pipeline to the flare unit through an oil, condensate and other liquids collection unit. In doing so, the reverse flow of oil or condensate through the collection unit upon actuation of one of the valves shall be precluded. Where the hydrogen sulphide content in the gas exceeds 6 per cent, a special flare system shall be installed.
1415. Before well development, a reserve of drilling fluid of the appropriate density shall be kept, in a quantity of not less than one well volume, exclusive of the volume of fluid in the well, together with a reserve of materials and chemical reagents for the prompt preparation of a further volume of drilling fluid.
1416. Where the product cannot be utilised, the development and testing of production wells shall be prohibited. The development of exploratory wells shall be permitted where the production is neutralised by flaring the gas, for not more than 45 hours per facility.
1417. The inducement of inflow and testing of the well shall be carried out only during daylight hours, with the wind direction away from the nearest populated areas.
1418. During the period of inducing inflow from the formation and well killing, the following shall be ensured: continuous round-the-clock duty of responsible persons authorised by the customer to carry out this work, in accordance with a schedule approved by the technical manager of the organisation; round-the-clock standby of evacuation transport; constant readiness for operation of cementing units; readiness of the population and workers for protection in the event of an emergency release.
1419. Where there is no inflow, well development shall be carried out using: natural or associated petroleum gas; two-phase and multi-phase foams inert to hydrogen sulphide and carbon dioxide; inert gases; a lower-density fluid inert to hydrogen sulphide and carbon dioxide. The use of air for these purposes shall be prohibited.
1420. It shall be prohibited, during well testing and development, to approach the wellhead, pipelines, distribution panels or separation units without isolating breathing apparatus.
1421. It shall be prohibited to carry out well development in the floodplain zones of rivers during the flood period.
1422. The wireline used for downhole surveys shall be corrosion-resistant and of one-piece construction. When being pulled out, the wireline shall pass through a sealed device fitted with a hydrogen sulphide neutraliser.
1423. Before opening the valve on the outlet assembly, and also when running in or pulling out a downhole instrument, workers not involved in these operations shall be moved to a safe distance on the windward side.
1424. Valves on the outlet assembly shall be opened, and instruments shall be removed from the lubricator and dismantled, while wearing isolating breathing apparatus.
1425. On completion of well development or testing, instruments, equipment and protective clothing shall undergo special treatment to neutralise hydrogen sulphide.
1426. On completion of the work, monitoring of the working area air for the presence of hydrogen sulphide and a check of the leak-tightness of the wellhead assembly shall be carried out.
1427. Surface equipment shall have blowdown and emergency (well-killing) lines not less than 100 metres long, pressure-tested with a safety factor of 1.25 times the expected maximum pressure. The lines shall be fitted with check valves and shall allow for the connection of monitoring and recording instruments.
1428. It shall be prohibited to operate a well by natural flow without downhole equipment, including: a landing nipple for the intake valve and a blanking plug; a packer to protect the production string, a circulation valve, an inhibitor valve, and a wellhead shut-off valve. After installation, the packer shall be pressure-tested for leak-tightness, and the well annulus above the packer shall be filled with inhibitor fluid. In exploratory wells, the development and testing of wells without downhole equipment shall be permitted, provided the production and tubing strings are inhibited.
1429. Control of the central valve, the first side valves from the wellhead installed on the christmas tree wings, and the wellhead shut-off valve shall be remote and automatic.
1430. During operation, the shut-off valve shall be periodically tested for actuation in accordance with the manufacturer's recommendations (instructions).
1431. Wells and flow lines shall be inspected daily during rounds by a mobile team of not less than two operators, equipped with breathing apparatus, air monitoring devices and communication equipment. The results of inspections shall be recorded in a special logbook.
1432. Where a leak of oil or gas containing hydrogen sulphide is detected in the wellhead assembly, the well shall be closed immediately using the corresponding valve or the wellhead shut-off valve from the control panel. Where a leak of hydrogen sulphide is detected from the well flow line, the valve on the flow line and the inlet valve on the metering unit shall be closed from the control panel. These occurrences shall be promptly reported to the facility manager and to the professional emergency rescue service (PASF) personnel.
1433. Monitoring of MKD (inter-string annulus pressure) shall be carried out during well operation. Where pressure is detected in the inter-string annulus, well operation shall be discontinued. The decision on further operation of the well is taken by the organisation operating the hazardous production facility, on the basis of the results of investigations and after measures have been taken to identify and eliminate the causes of the MKD.
1434. Before starting repair work (replacement of the wellhead assembly, repair of downhole equipment and other in-well operations) involving depressurisation of the wellhead, fluid of a density corresponding to the drilling design or the work plan for the well, treated with a hydrogen sulphide neutraliser, shall be pumped into the well. Repairs on the well shall be carried out in accordance with the approved plan.
1435. At the wellhead of a flowing well, for the period of repairs involving depressurisation of the wellhead, BOP equipment shall be installed, which shall include a preventer with shear rams.
1436. Where indications of a kick (GNVP) appear, repair work on the well shall be stopped immediately and measures taken to eliminate the complication.
1437. During breaks in work on re-equipping the wellhead, or replacing crosses, BOP equipment or the christmas tree, it shall be prohibited to leave the wellhead open.
1438. The automation system for producing wells and near-wellbore equipment shall ensure: the supply of reagent to the well and the cessation of its supply in the event of possible emergency situations, and signalling of emergency deviations of process parameters; automatic shut-down of wells in the event of a deviation from the operating mode; monitoring of the condition of the air environment at field facilities with remote shut-down thereof in the event of depressurisation of process equipment (pipelines).
1439. Checks of the leak-tightness of flange connections, valves, hatches and other sources of possible hydrogen sulphide emissions are carried out by the organisation. The check is carried out by means of a daily inspection round of each hazardous facility. The results of the inspection round shall be recorded in the relevant logbook.
1440. For pumping media containing hydrogen sulphide, pumps of sealless design or fitted with electromagnetic couplings shall be used.
1441. Waste water from oil, gas and gas condensate treatment units shall undergo purification and, where the content of hydrogen sulphide and other harmful substances exceeds the MPC, neutralisation.
1442. Before opening and depressurising process equipment, actions to deactivate pyrophoric deposits shall be carried out. Before inspection and repair, tanks and vessels shall be steamed and washed with water to prevent the spontaneous combustion of pyrophoric deposits. Actions to deactivate pyrophoric compounds shall be carried out using foam systems based on surfactants or other methods that wash the compounds off the walls of the vessels.
1443. Work inside a tank or vessel may be started only if the hydrogen sulphide, petroleum gas and oil vapour content therein does not exceed the MPC, and only while wearing breathing apparatus. The procedure for safely carrying out cleaning, pyrophoric deposit deactivation, inspection and repair work on such equipment shall be set out in a special instruction approved by the technical manager of the organisation.
1444. To prevent the spontaneous combustion of pyrophoric deposits during repair work, all components and parts of process equipment being dismantled shall be moistened with technical cleaning agents.
1445. To prevent the ignition of pyrophoric deposits on the walls of tanks and vessels, before preparation for inspection and repair the latter shall be filled with steam or water as they are emptied. Steam shall be supplied at an intensity such that a pressure slightly above atmospheric is maintained in the tanks and vessels at all times. The steam flow rate shall be monitored by the discharge from the top of the tank or vessel. During the steaming of vessels, tanks and reservoirs, the surface temperature shall not exceed 60°C.
1446. The duration of steaming shall be established individually by the relevant instructions for each equipment size and type, but shall be not less than 24 hours. Vessels shall be steamed with the hatches closed, and reservoirs with the breather valve open.
1447. At the end of the steaming period, the pyrophoric deposits shall be deactivated (by controlled oxidation with atmospheric oxygen) by feeding into the equipment, using metering devices (control flow meters), a metered steam-air mixture with an oxygen content of 3-8 per cent by volume (15-40 per cent by volume of air) for 3-6 hours, respectively. On completion of steaming, the equipment shall be filled with water to the upper level. After filling, to ensure the slow oxidation of pyrophoric deposits, the water level shall be reduced at a rate of not more than 0.5 m/h. At sub-zero ambient air temperatures, the equipment shall be flushed (filled) with heated water or with water and steam.
1448. Stationary or mobile standard equipment and utilities for the supply of steam and water shall be provided for flushing and steaming the equipment.
1449. On completion of flushing, the equipment shall be ventilated with air (initially with a small inflow of steam). Hatches for ventilating the equipment shall be opened starting from the top one, so as to avoid intensive movement of atmospheric air within it.
1450. Work to clean equipment of pyrophoric deposits carried out by mechanised means (for example, through the lower manhole using a scraper with an intake and suction device) not requiring the presence of workers inside the equipment, shall be permitted to be carried out without prior steaming and degassing, in accordance with a special instruction approved by the technical manager of the organisation. In doing so, the equipment shall be freed of the flammable product, disconnected from all pipelines by blanks, its internal space filled with medium- or high-expansion air-mechanical foam, and, during the cleaning work, the constant filling of the equipment with foam shall be ensured. Conditions precluding the occurrence of a static electricity discharge shall be ensured while the work is carried out.
1451. Deposits removed from the equipment shall be kept under a layer of water or in a moist condition in special containers installed away from places where flammable vapours and gases may be released or accumulate.
1452. On completion of the cleaning of the equipment, the pyrophoric deposits shall be removed from the facility site in a moist condition to a specially designated place, or placed in waste disposal facilities included in the state register of waste disposal facilities.
1453. Where gas and product pipelines with a large geometric volume are present at production facilities, they shall be sectioned by installing automatic valves ensuring that each section contains not more than 2000-4000 nm3 of hydrogen sulphide under normal operating conditions.
1454. Perforation and geophysical operations (PGR) in wells where formations containing hydrogen sulphide have been opened shall be carried out in accordance with a work plan approved by the technical managers of the geophysical and drilling organisations and by the subsurface user (customer), and agreed with the professional emergency rescue service (PASF).
1455. Perforation and geophysical operations (PGR) may be carried out only after checking the condition of the well, equipment and communication facilities, with a report drawn up. Before carrying out perforating and blasting operations (PVR), during gauging of the well, the hydrostatic pressure in the perforation interval shall be determined. Perforating and blasting operations (PVR) shall be permitted only where the measured hydrostatic pressure exceeds the formation pressure by not less than 5-10 per cent.
1456. Testing of formations containing hydrogen sulphide with drill-stem testers during well drilling shall be carried out in accordance with plans approved by the subsurface user (customer).
1457. The condition of the windows of geophysical laboratory and hoist cabins shall ensure a good view of the working area and the possibility of rapid ventilation of the cabin.
1458. When working in conditions that hinder the signalling of the presence of hydrogen sulphide (wind, snow, fog, difficult weather conditions), the PGR manager shall designate a worker to monitor these devices, who shall be instructed and provided with the necessary PPE and means of communication.
1459. PGR in complicated conditions, as well as PVR to eliminate accidents in wells, shall be carried out under the direct supervision of the responsible person of the geophysical organisation.
1460. Equipment, apparatus, pipelines, as well as downhole equipment, drill pipe, casing and tubing exposed to hydrogen sulphide, shall be selected taking into account the parameters of the process operations and the characteristics of the corrosive environment. The areas of use of equipment in standard design and in a design resistant to sulphide stress cracking (SSC) are indicated in Tables No. 1 and No. 2 of Appendix No. 4 to these Rules. Inhibitor protection shall be ensured during the operation of the equipment.
1461. Where there are deviations from the established criteria for equipment selection, by agreement with the organisation operating the hazardous production facility, the use of standard equipment in a corrosive environment, with the mandatory supply of a corrosion inhibitor, and the shortening of the intervals for control testing (inspections), shall be permitted.
1462. A tank for fluid containing hydrogen sulphide shall be fitted with an upper level alarm and a lower sampling point.
1463. To protect against corrosion the process equipment and pipelines of oil, gas and condensate production, gathering, treatment and transport systems, the production and tubing strings, downhole and other equipment operated under conditions of exposure to hydrogen sulphide, corrosion inhibitors, special coatings and process methods for reducing the corrosivity of the product shall be applied.
1464. The BOP manifold, drill pipe, tubing and pipelines that have been in contact with hydrogen sulphide shall, after dismantling and before reuse, undergo flaw detection and pressure testing.
1465. Casing and tubing pipes used shall undergo laboratory testing for chemical composition and other steel quality indicators.
1466. Monitoring of the corrosion condition of equipment, in addition to visual inspection, shall be carried out by the following methods: installation of control specimens; corrosion rate sensors; corrosion monitoring assemblies; hydrogen probes; ultrasonic and magnetic thickness gauging. The methods, frequency and points of corrosion monitoring for each type of equipment and pipeline shall be established in accordance with the recommendations of research and design organisations and approved by the technical manager of the organisation. Depending on the absolute pressure Pabs, the partial pressure of hydrogen sulphide P and its concentration C for a multiphase oil-gas-water fluid with a gas factor of less than or more than 890 nm3/m3, equipment in standard design and in a design resistant to SSC shall be applied in accordance with Appendix No. 4 to these Rules.
1467. Persons who hold a medical certificate of fitness to work in isolating breathing apparatus, who have undergone the necessary safety training for work at the facility, and who have been checked on their knowledge and skills in using respiratory protective equipment, shall be admitted to work at facilities of fields with a high hydrogen sulphide content.
1468. Persons who do not have the appropriate breathing apparatus and have not undergone the appropriate safety induction shall be prohibited from being present at a gas-hazardous facility.
1469. Not less than once a month, training exercises shall be conducted with workers at the facilities to develop practical skills in carrying out actions under the PMLA.
1470. When working in breathing apparatus at the wellhead or at another source of hydrogen sulphide release, the workers and the person in charge of the work shall have an explosion-proof radio communication device.
1471. Where gas detectors (gas analysers) are triggered indicating that the hydrogen sulphide content exceeds the MPC, the following shall be done immediately: put on isolating breathing apparatus (a gas mask); notify the person in charge of the work (facility) and the persons in the hazard area; take priority measures to eliminate the gas contamination in accordance with the PMLA; persons not involved in taking priority measures shall leave the hazard area and proceed to the assembly point established in the evacuation plan. The person in charge of the work (facility) or the responsible executive shall raise the alarm and notify higher-level organisations.
1472. Workers of third-party organisations engaged for work at gas-hazardous facilities shall undergo training and a knowledge check to an extent approved by the chief engineer of the customer organisation, taking into account the location and type of work, in the manner established by the customer organisation, and shall have individual gas detectors.
1473. The quantity and types of PPE and respiratory protective equipment at each facility shall be determined by the design documentation and the well drilling design, taking into account the specific nature of the work and the industry standards for providing workers with protective clothing, protective footwear and other PPE. Where required by production needs, taking into account the specific features of production, working conditions and the types of work performed, as well as the features of the climatic zone, the employer may issue workers with certified protective clothing, protective footwear and other PPE in excess of the established standards, or change the periods for wearing them, to ensure the safety of the labour process. The collective and personal protective equipment for workers of construction and other organisations located within the buffer zones, and the procedure for providing such equipment in the event of an emergency gas release, shall be determined by the design documentation and the well drilling design.
1474. Isolating breathing apparatus shall be used by workers when carrying out operations provided for by the work process technology under conditions of possible hydrogen sulphide release, and when taking priority measures in the event of an emergency situation.
1475. Breathing apparatus shall be selected to fit. Each apparatus shall be accompanied by a data sheet and shall have a label attached bearing the worker's surname and initials. The data sheet shall contain an entry on the serviceability of the breathing apparatus and the dates of its next test.
1476. The operating organisation shall check gas protection equipment for compliance with the indicators established by the manufacturer.
1477. An instruction on the checking, operation and storage of protective equipment shall be available at the workplaces.
1478. An emergency reserve of gas protection equipment shall be maintained at the gas-hazardous facility, the quantity and types of which shall be determined taking into account the number of workers, the remoteness of the facility and the specific nature of the work performed.
1479. In addition to certification in industrial safety, managers and workers shall undergo a check of their knowledge of the requirements of regulatory legal acts in the field of sanitary and epidemiological welfare of the population, environmental protection and labour protection.
1480. Internal monitoring of compliance with industrial safety requirements is carried out by organisations, taking into account the specific conditions of production.
1481. The training programme for workers at hydrogen sulphide-containing oil and gas treatment facilities shall, among its main sections, additionally provide for the following: the properties and effects of hydrogen sulphide and other harmful substances on the human body; PPE, its purpose, design and rules of use; safety signs, signal colours and emergency notification signals; the procedure, methods and means of monitoring the working area air; safe work practices and methods; safety measures and the procedure for action in the event of possible emergency situations and the threat of their occurrence; methods and means of providing first aid to casualties.
1482. Process regulations shall apply to the development of actions and the performance of work aimed at the safe operation of hazardous production facilities.
1483. Process regulations for the design and construction stage, as well as for reconstruction, shall be prepared by the design organisation. Process regulations for a hazardous production facility already in operation may be prepared by the operating organisation.
1484. Process regulations are the principal process document and define the technology for conducting the process or its individual stages (operations), the production modes and formulation, the product quality indicators, and safe working conditions in accordance with the applicable regulatory technical documents.
1485. Process regulations shall ensure safe working conditions, the operation of equipment within its rated (data sheet) parameters, the economic conduct of the process, and the specified product quality.
1486. The technical manager of the operating organisation is responsible for compliance with the requirements of the process regulations.
1487. Process regulations shall be developed for each process. It shall be permitted to develop a single set of process regulations for a hazardous production facility as a whole, or for several hazardous production facilities linked by a single process.
1488. The recommended content of the sections of the process regulations is set out in Appendix No. 9 to these Rules.
1489. Where trial operation or the testing of new equipment is carried out at an operating hazardous production facility with approved process regulations, separate process regulations shall be developed. It shall be permitted to develop supplements to the existing process regulations. The question of developing separate process regulations or supplements to the existing process regulations shall be decided by the organisation approving the process regulations.
1490. Process regulations developed within the operating organisation shall be agreed with the relevant technical services and approved by the technical manager of the operating organisation.
1491. Process regulations shall be developed for a period of 5 years. Where the process regulations referred to in paragraph 1489 of these Rules are developed, the validity period of the process regulations shall be determined by the period of trial operation or testing of the new equipment and shall be limited to 2 years.
1492. Where changes and additions have been made that do not impede the use of the process regulations, or where none have been made, the validity period of the process regulations shall be extended for a further 5 years, but not more than once.
1493. On the expiry of two five-year periods, the process regulations shall be subject to mandatory revision. The revised process regulations shall be agreed within the organisation with the relevant technical services and approved by the chief engineer (technical director) of the organisation.
1494. The process regulations shall be revised ahead of schedule in the event of: the entry into force by federal executive authorities of new provisions and restrictions that conflict with clauses or sections of the process regulations; accidents that occurred owing to the safe operating conditions being insufficiently reflected in the process regulations; the presence of fundamental changes in the technology or equipment configuration, the incorporation of which into the process regulations would require changes to a significant number of sections and clauses of the process regulations.
1495. The text part of the process regulations shall be prepared in A4 format.
1496. Each set of process regulations shall be assigned a number or designation in accordance with the procedure adopted by the organisation.
1497. The approved process regulations shall be kept in the technical department of the organisation. Copies and extracts from the process regulations, certified by the technical department of the organisation, shall be provided to the managers of the units for the purposes of managing and maintaining the process mode, and to other interested organisations.
1498. Changes and additions relating to changes in feedstock quality, the need to change loads or modes, or the replacement of equipment, may be made to existing process regulations. New process regulations shall be developed in the event of reconstruction or technical upgrading.
1499. Changes and additions shall be agreed with the technical services of the organisation directly concerned with them, and approved by the chief engineer (technical manager) of the organisation. Changes and their registration shall be carried out in accordance with Appendix No. 10 to these Rules.
1500. The subsurface user shall ensure the abandonment of wells not subject to further use, and the preservation of wells that may be used in field development and (or) for other economic purposes.
1501. The suspension and abandonment of wells are carried out in accordance with documentation developed: as part of projects for the prospecting, exploration and development of fields, underground oil and gas storage facilities and facilities for the utilisation of thermal water heat-power resources, and working projects for drilling operations and well reconstruction; in individual, group (a group of wells with their numbers indicated within a single field) and zonal (a group of wells with their numbers indicated across several areas and fields having identical geological, mining and environmental characteristics) documentation for the abandonment and suspension of wells; in individual documentation for fields with a complex geological structure or a high content of corrosive and toxic components.
1502. Documentation for the abandonment and suspension of wells for regions and fields with uniform geological, mining and environmental conditions establishes general requirements for the abandonment and suspension of wells at the field (area) concerned or at several fields of the same type. The detailed performance of operations for each specific well is set out in the isolation and abandonment operations plan.
1503. Documentation for the abandonment and (or) suspension of wells includes the following sections: a general explanatory note, including justification of the criteria and option for the abandonment and (or) suspension of wells, and the option for abandonment and (or) suspension (depending on the stage of drilling or operation of the wells); process and technical solutions for the abandonment and (or) suspension of wells and the equipping of the wellbore and wellhead; the procedure for organising work on the abandonment and (or) suspension of wells; actions for the safe use of subsoil, the safety of life and health of the population, and the protection of the environment, buildings and structures.
1504. Operations for the abandonment and suspension of wells (taking into account the results of inspection of the technical condition of the wells) are carried out by the subsoil user or its representative (hereinafter referred to as the organisation operating the hazardous production facility).
1505. The abandonment and suspension of a well is deemed completed once the abandonment or suspension report has been signed by the organisation operating the hazardous production facility and the territorial authority of Rostechnadzor.
1506. Abandoned wells are excluded from the information describing the hazardous production facility and from the certificate of registration of the hazardous production facility in the State Register.
1507. Additional requirements for the suspension and abandonment of wells drilled offshore are established in paragraphs 1510 to 1526 of these Rules.
1508. The abandonment and suspension of wells in flood-prone areas (except wetlands) and in the beds of large (navigable) rivers are carried out with due regard to the requirements of paragraph 1549 of these Rules.
1509. Monitoring of the condition of the wellheads of abandoned and suspended wells is carried out by the subsoil user or its authorised representative in accordance with the subsoil use licences in force.
1510. A plan for the safe performance of isolation and abandonment operations is drawn up for each well being abandoned or suspended, taking into account the results of inspection of its technical condition; the plan is agreed with the organisation carrying out the abandonment or suspension operations and approved by the operating organisation. The plan specifies: the well design (well depth, the diameter and lengths of the casing strings run, and the height of cement rise in the annulus behind the casing strings) and its condition (the nature of the complication, the presence of any tools and the interval of their location in the wellbore); the reason for abandoning or suspending the well; the operations carried out in the well, the density of the drilling fluid, the intervals for setting cement plugs, and the quantity of cement to be pumped; dismantling (installation) work at the wellhead; and the persons responsible for carrying out the operations specified.
1511. When abandoning and suspending wells that have penetrated oil and gas formations with a hydrogen sulphide content of more than 1 per cent by volume in the fluid produced from them, measures are provided to prevent the corrosive effect of hydrogen sulphide on the casing strings and cement plugs. Documentation for the abandonment or suspension of wells with a subsea wellhead is agreed with the relevant hydrographic service.
1512. In all wells being abandoned, a cement plug not less than 50 m in height is set in the last (smallest) casing string connected to the wellhead, with the top of the cement plug positioned at seabed level.
1513. When abandoning wells drilled from a mobile offshore drilling unit (MODU), the casing string protruding above the seabed (where a special system of subsea hangers or wellhead housings was not used during drilling of the well) is removed down to seabed level. The coordinates of the wellhead location are transmitted to the relevant services for inclusion on navigation charts.
1514. After completion of the operations to remove the MODU from the drilling location, a survey of the seabed is carried out to confirm the absence of navigational hazards, together with video recording of the wellhead and the seabed within a radius of 10 m. One copy of the survey report, drawn up by the operating organisation, is submitted to the hydrographic service. The seabed survey operations are carried out by a specialised organisation.
1515. The results of testing cement plugs by slacking off the drill string and pressure-testing them are recorded in a corresponding report drawn up by the operating organisation. Cementing packers and plugs (retainers) may be used to isolate the test intervals during the abandonment and suspension of wells. The presence of a plug is checked by slacking off the drill string or tubing with a force not exceeding the maximum permissible specific load on the cement stone. Cement plugs, cementing packers and plugs (retainers) are tested by pressure-testing at the pressure established in the documentation for the abandonment and suspension of wells, taking into account the residual strength of the casing strings.
1516. A well is suspended in such a manner as to ensure that it can subsequently be brought back into operation or that repair and other work can be carried out in it.
1517. The suspension and abandonment of a well with inter-casing leaks of gas, oil or water shall not be permitted.
1518. On wells that have been suspended, inspections of the condition of the equipment and the presence of excess pressure at the wellhead are carried out at least once a year, with a survey report drawn up. If leaks are detected at the wellhead, or breakthroughs of gas or fluids at the seabed surface (gryphon formation) are detected, the professional emergency rescue service (PASF) shall be notified immediately.
1519. A marker post measuring not less than 0.4 x 0.2 x 0.005 m is installed at each well being suspended, on which the following are indicated by welding, indelible paint or another method ensuring the indelibility of the inscription: the well number, the name of the field (area) and of the operating organisation, and the date and duration of suspension.
1520. Each production well being suspended with an above-water wellhead is equipped with a Christmas tree. The handwheels of the valves (except for the valve performing the function of a control valve) are removed, the piping connections of the tree are disconnected, and the outer flanges of the tree valves are fitted with blind flanges; pressure gauges (except for the control gauge) are removed and their mounting points are blanked off.
1521. The procedure for equipping the wellbore when suspending wells that have completed drilling is determined depending on the magnitude of the formation pressures and the duration of well suspension.
1522. When a well is suspended, a special capping head, together with anti-trawl protection, is installed on the subsea wellhead to seal the subsea wellhead, or special shut-off equipment is used to seal the wellhead.
1523. The location of the subsea wellhead is determined by means of satellite navigation.
1524. After completion of the operations for suspending (abandoning) a well, the geological service of the organisation performing the operations draws up a certificate of well suspension (abandonment). A copy of the certificate is transmitted to the operating organisation, which draws up a report on the suspension (abandonment) of the well.
1525. The development, agreement and approval of documentation for the reactivation of wells from suspension are carried out in the procedure established for the development, agreement and approval of documentation for the suspension of wells.
1526. The subsoil user or its representative monitors the condition of the wellheads of abandoned wells and the adjacent areas of the seabed. If a kick (gas, oil or water influx) is detected, the subsoil user or its representative organises and carries out workover and isolation operations on the abandoned wells and carries out repeat abandonment.
1527. All wells being abandoned are divided, depending on the reasons for abandonment, into four categories: I - wells that have fulfilled their purpose; II - wells abandoned for geological reasons; III - wells abandoned for technical reasons; IV - wells abandoned for process, environmental and other reasons.
1528. Category I - wells that have fulfilled their purpose. These include: I-a - wells that have fulfilled the tasks set out in the field development project technological documents and the working projects for drilling operations or well reconstruction; I-b - wells that have reached the lower flow-rate limit established by the field development project technological document or another justification of the lower profitability limit for production wells, that have been watered out by formation water or injected water, that have no return or commingling objects, where there is no need to transfer them to the control (observation, piezometric) well stock; I-c - wells drilled to carry out experimental and pilot-industrial operations for testing various technologies and production facilities, or for extinguishing fires, blowouts and gryphons, after completion of the tasks established by the project technological document; I-d - wells drilled as producing wells and, after watering out, converted to control, injection or other wells, where there is no need for their further use; I-e - wells that have fulfilled their purpose at underground oil and gas storage facilities and thermal and industrial water fields.
1529. Category II - wells, or parts of their wellbore, abandoned for geological reasons. These include: II-a - wells drilled to the design depth but found to be in unfavourable geological conditions - in zones with no reservoir rock, or in the off-structure area of oil and gas fields, that have yielded non-commercial inflows of oil, gas or water, including after stimulation; II-b - wells whose drilling was discontinued owing to the inexpediency of continuing operations, based on the results of drilling previous wells; II-c - wells that have not penetrated the design horizon and have not been drilled to the design depth owing to a discrepancy between the actual and design geological section, or the encountering in the section of insurmountable obstacles (catastrophic lost-circulation zones, cavings, highly plastic rock, or zones with abnormally low or abnormally high formation pressure); II-d - wells that have completed drilling at underground oil and gas storage facilities and heat-power and industrial water fields and are found to be in geological conditions not corresponding to their purpose; II-e - injection, observation, production, iodine-bromine, geothermal and balneological wells, and also wells drilled for the injection of field-produced water into a formation, for the disposal of industrial waste, or for the operation of underground oil and gas storage facilities, that are found to be in unfavourable geological conditions where there is no need for their use for other economic purposes.
1530. Category III - wells, or parts of their wellbore, abandoned for technical reasons (emergency wells), which include wells where drilling, workover operations or production have been discontinued owing to accidents, incidents and complications that cannot be remedied by existing methods or that it is not economically viable to remedy: III-a - wells on which open blowouts or fires have occurred resulting in the loss of the wellbore, as well as accidents involving the drill string and its components, accidents involving casing pipes and their components, stuck drill or casing strings, accidents involving drill bits and core bits, accidents involving downhole motors and turbodrills, downhole and wellhead equipment, geophysical tools and cable, and accidents due to poor-quality cementing (where the sound section of the wellbore above the emergency section contains productive horizons of commercial significance that, in accordance with the field development project technological document, are to be produced through that well, only the emergency section of the wellbore is abandoned, and the sound section is transferred to the producing enterprise); III-b - wells in which an inflow of formation water occurred during well completion, testing or operation and cannot be isolated; III-c - wells in which a loss of integrity of the production casing has been identified and for which there is no technical possibility or economic viability of restoring them; III-d - wells whose wellheads have been destroyed as a result of natural disasters (earthquakes, landslides) or where there is a risk of landslide phenomena or flooding; III-e - wells with collapsed or broken casing strings in intervals containing salt, clay or permafrost, and for which there is no technical possibility or economic viability of restoring them; III-f - wells drilled at offshore fields in the event of an emergency departure of drilling rigs, destruction of hydraulic engineering structures, or technical impossibility and economic inexpediency of restoring them; III-g - wells drilled with impermissible deviations from the design point of formation penetration.
1531. Category IV - wells abandoned for process, environmental and other reasons. These include: IV-a - wells that have completed drilling and are unsuitable for operation owing to a discrepancy between the strength and corrosion-resistance characteristics of the production casing and the actual conditions; IV-b - wells unsuitable for operation under conditions involving thermal and gas methods of formation stimulation; IV-c - wells suspended pending the organisation of production, where the suspension period is 10 years or more but not more than 15 years of the total suspension period, or where, according to monitoring data on the technical condition of the casing and cement stone, further suspension is not expedient; IV-d - wells located in sanitary protection zones of populated areas, water protection zones of rivers and water bodies, or restricted zones, abandoned at the request of authorised bodies; IV-e - injection wells whose injectivity has ceased, wells at underground storage facilities, and wells intended for the discharge of field-produced water and production waste, where it is not possible or economically expedient to restore their injectivity; IV-f - wells that are special facilities, the abandonment of which, after fulfilment of their design purpose, is carried out in accordance with the requirements of these Rules; IV-g - wells located in zones where the understanding of the geological situation has changed, entailing a change in environmental and sanitary requirements and safety measures, and where the operation of the wells has become inconsistent with the status of those zones; IV-h - wells that have not penetrated the design horizon and have not been drilled to the design depth owing to the occurrence of long-lasting force majeure circumstances, the bankruptcy of the enterprise, a lack of financing, the cessation of the enterprise's activities, or the expiry of the subsoil use licence.
1532. The category by which a well is abandoned is determined by the subsoil user or its representative. Equipping of wellheads and wellbores of wells during their abandonment. Organisational and technical requirements
1533. The abandonment of wells with a loss of casing string integrity, behind-casing crossflows or gryphons may be carried out only after these have been eliminated. The well abandonment report specifies the list of operations performed, the results of studies verifying the reliability of these operations, and a conclusion on the unsuitability of the well for its further safe operation.
1534. In complex geological and mining conditions of the section, or where it contains sources of inter-formation fluid flow (IFF) and inter-casing pressure (ICP), wells are abandoned by creating a system of fluid-tight cementing barriers and plugs that isolate the sources of IFF and ICP and restore the separation between the penetrated rocks or their complexes, which was disturbed during the drilling of the well.
1535. The wellbore between the cement plugs and above the last plug is filled with a neutral fluid. The upper part of the wellbore is filled with a neutral non-freezing fluid, the height of the column of which is determined taking into account the location of the well and the technical objectives to be achieved.
1536. Before abandonment operations are carried out, a diagnostic assessment of the technical condition of the well is carried out using the available geological and field data, taking into account the latest well logging survey; potentially hazardous formations that are sources of IFF and ICP in the penetrated section are identified, and their isolation shall be provided for in the well abandonment documentation.
1537. ICP and IFF of formation fluids are eliminated in the course of abandonment operations, starting from the lower part of the wellbore. Complications and accidents arising during isolation and abandonment operations in the well are eliminated under supplementary plans for the abandonment of wells.
1538. The setting of fluid-tight barriers, caprocks and cement plugs aimed at eliminating ICP, eliminating and preventing the occurrence of IFF, and restoring the integrity of the geological section, is carried out under excess pressure, the value of which is adopted taking into account the residual strength of the casing string.
1539. The presence of plugs is checked by slacking off the drill string or tubing with a force not exceeding the maximum permissible specific load on the cement stone. Testing of the cement plugs set is carried out using excess pressure in accordance with paragraph 1538 of these Rules.
1540. Where the section of a well being abandoned contains promising intervals not previously tested, or where drainage of a source of IFF and ICP is necessary, their penetration, testing and drainage are carried out by decision of the subsoil user. The penetrated intervals are isolated by creating a fluid-tight isolation barrier and securing it by injecting cementing slurry into the formation under pressure.
1541. The separation of rock complexes having different formation pressure abnormality coefficients, and the prevention or elimination of crossflows of formation fluids from one rock complex to another, are ensured by setting isolation barriers in the intervals of caprock lying at the base and top of the various rock complexes, which differ from one another in the value of the formation pressure abnormality coefficient or in the formation fluids contained within them.
1542. Where a well is located in any process zone associated with an impact on underground reservoirs (underground gas storage facilities, sites for the injection of industrial effluents, chemical waste, corrosive and toxic components and others), or in the zone of their influence, additional isolating cementing barriers are set in the intervals of the base and top caprock bounding the vertical extent of the process zone.
1543. Where the sedimentary cover section of a field contains a zone of weakly mineralised and drinking-quality upper waters or permafrost, isolation barriers (not less than one) are created in the base aquicludes and below the interval of permafrost occurrence during the abandonment of wells.
1544. The documentation for the abandonment of wells shall provide for the complete retrieval of downhole equipment and drilling tools from the wellbore down to the drilled total depth. Where there is no technical possibility of retrieving downhole equipment and drilling tools from the wellbore, an addendum to the isolation and abandonment operations plan is developed.
1545. A concrete plinth measuring 1.0 x 1.0 x 1.0 m is installed at the wellhead (the use of metal formwork with a diameter of not less than 0.5 m and a height of 1.0 m is permitted). A marker post not less than 0.5 m in height, with a metal plate on which the following are indicated by electric welding, is installed on the plinth: the well number, the date of its abandonment, the field (area) and the subsoil-user organisation.
1546. Where a well is located on land used for agricultural purposes and on land of non-industrial categories, the wellhead is lowered not less than 0.8 m below the surface and equipped with a blank flange fitted on the surface casing (intermediate casing) and a plate indicating the well number, the field (area), the subsoil-user organisation and the date of its abandonment. The blank flange is coated with a material preventing its corrosion, and the wellhead is backfilled with soil. An extract from the site plan indicating the location of the wellhead of the abandoned well is transmitted to the land user, and a corresponding note is made in the well file and in the land reclamation report.
1547. When land is transferred from one category to another (from the category of agricultural land to the category of land of populated areas or land of specially protected natural areas), the wellheads are re-equipped in accordance with paragraphs 1545 and 1549 of these Rules.
1548. For wells abandoned under Category III, and also for wells of all categories drilled within the outer contour of oil-and-gas-bearing capacity and the maximum size of the artificial gas storage deposit, cement plugs are set in the interval and 20 m below and above the thickness of all productive horizons whose productivity has been established during the drilling of wells, the development of the field, or the operation of the storage facility.
1549. Where wells are located in flood-prone areas and in the beds of large (navigable) rivers, the casing string, surface casing and drive pipe are retrieved from a depth of 10 m below the riverbed. Where the passage of vessels in the flood-prone area is precluded and agricultural work is planned after the end of the spring flood, the casing string, surface casing and drive pipe are retrieved from a depth of not less than 2 m below ground surface.
1550. The abandonment of a well without a production casing, depending on the geological and mining conditions of the penetrated section, is carried out by setting cement plugs in the open hole in the intervals containing high-pressure mineralised waters with an abnormality coefficient greater than 1.1 and low-productivity hydrocarbon deposits of no commercial significance. The height of the cement plug shall be 20 m below the base and the same distance above the top of each such horizon.
1551. Above the top of the uppermost formation containing mineralised water, and also at the boundary between formations containing fresh water and mineralised water (where they are not covered by intermediate casing), a cement plug 50 m in height is set.
1552. A cement plug is set at the shoe of the last intermediate casing, overlapping the casing shoe by not less than 50 m above and 20 m below the casing shoe.
1553. The presence of plugs is checked by slacking off the drill string or tubing with a force not exceeding the maximum permissible specific load on the cement stone. The cement plug set at the shoe of the last intermediate casing is pressure-tested to the pressure specified in the work plan. The results of the operations are recorded in corresponding reports. The open hole between the plugs and the casing annulus are filled with a neutral drilling fluid of the density established in the well abandonment documentation, and the upper part of the casing annulus is filled with a neutral non-freezing fluid.
1554. The retrieval of the upper part of the intermediate casing with an uncemented annulus is permitted where the section contains no pressurised or productive horizons. In this case, a cement plug is set in the remaining part of the intermediate casing, extending 50 m above and 20 m below the point of casing retrieval. The remaining part of the intermediate casing is filled with a neutral fluid, and the surface casing with a neutral non-freezing fluid.
1555. When abandoning wells as a result of an accident (Category III-a) in the uncased part of the wellbore, where retrieval of the tools is not possible, the unstuck part of the tools shall be severed by backing off or torpedoing and retrieved. Where the top of the tools remaining in the well is located below the shoe of the intermediate casing or the surface casing, a cement plug is set under pressure, overlapping the head of the remaining tools by 50 m. After the waiting-on-cement period, the upper level of the cement plug shall be determined by slacking off the drill string or tubing. A cement plug 50 m in height shall also be set at the shoe of the intermediate casing, and its presence checked by slacking off the drill string or tubing, with hydraulic testing carried out by lowering the fluid level or replacing it with a lower-density fluid. Above the plug, the casing annulus is filled with a clay-based drilling fluid, above which the upper part of the casing is filled with a neutral non-freezing fluid.
1556. In the event of an accident involving a drill pipe string, where its upper part remains in the interval of the wellbore covered by the intermediate casing or the surface casing, the part of the drill string located above the shoe of the intermediate casing or the surface casing is retrieved, and pressure cementing is carried out with the setting of a cement plug at a level not less than 100 m above the shoe of the intermediate casing. The remaining part of the intermediate casing is filled with a clay-based drilling fluid. The upper part of the casing is filled with a neutral non-freezing fluid.
1557. Where, by decision of the subsoil user, the uncemented part of the production casing is backed off, a cement plug not less than 50 m in height is set above the head of the remaining part of the casing. The remaining part of the well is filled with a non-freezing neutral fluid. Where there is no cement stone behind the production casing below the shoe of the surface casing or the intermediate casing, and this interval contains reservoir formations bearing mineralised water or hydrocarbons, perforation of the casing and pressure cementing are carried out, and a cement plug is set in the casing in the interval 20 m below and above the perforation interval, followed by pressure testing and studies to determine the height of cement rise and its setting.
1558. When abandoning wells with a damaged casing due to an accident or corrosion of the production casing resulting from prolonged operation, studies are carried out to determine the presence and quality of the cement stone behind the casing, cementing is carried out in the intervals where it is absent, and a cement plug is set in the interval 20 m above and below the part of the casing affected by corrosion or accident-related damage, followed by testing of the remaining part of the casing and the plug by lowering the fluid level or replacing it with a lower-density fluid. The upper part of the wellbore is filled with a neutral non-freezing fluid.
1559. The abandonment of wells with a collapsed or displaced production casing is carried out by setting cement plugs in the intervals of perforation, displacement and collapse of the casing, 20 m below and 50 m above the last interval of perforation, displacement or collapse of the casing. Preceding perforation intervals are covered with cement plugs overlapping by 20 m above and below. The wellbore between the plugs and above them is filled with a neutral fluid, and the upper part of the wellbore is filled with a neutral non-freezing fluid.
1560. Where a well is located within the territory of an underground gas storage facility, the wellhead of abandoned wells may be equipped, for the purpose of monitoring the casing annuli, without installing a plinth, according to a scheme developed by the subsoil user or its representative.
1561. For wells that have penetrated low-yield, low-pressure formations with a pressure abnormality coefficient of less than 1.1, suspension cement plugs may be adopted as abandonment plugs, provided that the plug covers the entire perforation interval and extends not less than 50 m above it. The plug is tested by lowering the fluid level in the well or replacing it with a lower-density fluid. The wellbore above the plug is filled with a neutral fluid, and the upper part of the surface casing is filled with a neutral non-freezing fluid.
1562. When abandoning a well with emergency equipment in the wellbore, a cement plug shall be set under pressure in the perforation intervals, overlapping the head of the remaining tools by 20 m. After the waiting-on-cement period, the upper level of the cement plug shall be determined by slacking off the drill string or tubing.
1563. The wellhead shall be equipped with a blank flange (or a solid flange with a welded-in nipple and valve) fitted on the surface casing (intermediate casing).
1564. After the upper plug has been set, the casing annulus is pressure-tested at a pressure of 5 MPa.
1565. Above the top of the uppermost formation containing mineralised water (where it is not covered by the surface casing), a cement plug 50 m in height is set.
1566. When abandoning wells as a result of an accident involving downhole equipment (Category III-a), where retrieval of the equipment is not possible, the unstuck part of the tools shall be severed by torpedoing or backing off. Where the top of the equipment remaining in the well is located below the shoe of the surface casing, a cement plug shall be set under pressure, overlapping the head of the remaining tools by 50 m. After the waiting-on-cement period, the upper level of the cement plug shall be determined by slacking off the drill string or tubing. A cement plug 50 m in height shall also be set at the shoe of the surface casing, and its presence checked by slacking off the drill string or tubing and by pressure testing. Further operations are carried out in accordance with the requirements of these Rules. In the event of an accident involving downhole equipment where its upper part remains in the interval of the wellbore covered by the surface casing, it shall be torpedoed or backed off at the level of the casing shoe, and pressure cementing carried out with the setting of a cement plug at a level not less than 100 m above the shoe of the surface casing.
1567. To prepare the set of documents for well abandonment, the subsoil user or its representative establishes a commission. The commission includes representatives of the geological service, the drilling service, the chief engineer, and the industrial and environmental safety service. The chairman of the commission is appointed as the chief engineer or chief geologist of the subsoil user or its representative. Additional necessary employees (a geologist, an economist, a chief accountant) may be involved in the commission. The commission's decision on the abandonment of a group of wells (a well) is the basis for preparing the isolation and abandonment work plan for the specific well.
1568. Where the documentation for the abandonment of Category III-a wells contains no decisions, and also in the case of subsequent redrilling of the emergency section of the wellbore, the subsoil user or its representative develops an isolation and abandonment work plan, which is attached to the well file.
1569. In accordance with the decisions in the documentation for the abandonment of wells abandoned under Categories I-b, I-v, IV-b, IV-d, an isolation and abandonment work plan is drawn up, providing for actions for the safe use of subsoil, the safety of the life and health of the population, and environmental protection, on the basis of: (a) a statement containing information on the drilling history (with mandatory indication of the dates of commencement and cessation of drilling, testing, and accident-liquidation work, and, for Category IV wells, suspension), on operation, including the main values characterising the operation of the well (flow rates, pressures, cumulative production of oil, gas, and water), on workovers, conversions and recompletions carried out, on the design and as-built construction, on the reasons for deviation from the design, and on the reasons for well abandonment (with justification); (b) an extract from the structural map showing the design and as-built position of the wellhead and bottom, and, for production wells, a map of the current status of field development; (c) information on when and by whom the design documentation for the drilling of this well was prepared (the design technological document for field development or another design document on the basis of which the well was drilled), on who approved it, and on the actual and residual cost of the well; (d) standard well logs broken down by horizon with an interpretation for all productive formations penetrated, as well as an interpretation of the cementing quality check (by acoustic or other methods); (e) the results of pressure testing of casing strings and cement plugs, on the basis of certificates signed by the persons who performed the work; (f) the results of checking the technical condition of casing strings, on the basis of certificates signed by the persons who performed the work; (g) the opinion of the design organisation carrying out the preparation of the abandonment documentation.
1570. The well abandonment certificate (drawn up in accordance with Appendix No. 11 to these Rules), together with certificates of work performed signed by the persons who performed the work and certified by the subsoil user or its representative, as well as certificates (in the winter period, schedules and undertakings) for land reclamation work carried out and accident investigation reports with copies of orders on the results of the technical investigation of accident causes together with actions for their elimination and prevention, for wells abandoned for technical reasons, are submitted to the territorial office of Rostechnadzor. The recording of well abandonment certificates is carried out by the territorial offices of Rostechnadzor. The number and date of the abandonment certificate are assigned by the territorial office of Rostechnadzor after it is signed.
1571. All materials relating to the abandoned well, including the abandonment certificate signed by the parties, shall be bound and certified with a seal and signatures. The materials are kept by the subsoil user.
1572. The recording and annual monitoring of the condition of the wellheads of abandoned wells is carried out by the subsoil user. The frequency of inspections is established by the subsoil user, but not less than once every 2 years (for wells abandoned after the completion of drilling) and once a year (for wells abandoned during operation). Necessary repair work, where faults and violations of the requirements for the safe use of subsoil, the safety of the life and health of the population, and environmental protection are detected, is carried out by the subsoil user on the basis of work plans drawn up by the party performing the work and approved by the subsoil user or its representative.
1573. The restoration of previously abandoned wells is carried out in accordance with the relevant documentation and work plans.
1574. The repeat abandonment of restored wells (or a section of the wellbore) and the preparation of the abandonment materials is carried out in accordance with the documentation for repeat abandonment and the justification for the restoration work.
1575. Where repeat abandonment of wells is necessary, all work is carried out by the subsoil user or its representative in accordance with the documentation under the isolation and abandonment work plans. Procedure for well suspension. Organisational and technical requirements.
1576. The suspension of wells is carried out during drilling, after its completion, and during operation.
1577. The equipment of the wellhead and wellbore, the suspension period, and the procedure for monitoring the technical condition of suspended wells are carried out in accordance with the requirements of documentation developed by subsoil users or their authorised representatives, based on the specific mining and geological conditions. The recording of well suspension certificates is carried out by the territorial offices of Rostechnadzor. The number and date of the suspension certificate are assigned by the territorial office of Rostechnadzor after it is signed. All materials relating to the suspended well, including the suspension certificate signed by the parties, shall be bound and certified with a seal and signatures. The materials are kept by the subsoil user.
1578. The frequency of inspections of the condition of suspended wells is established by the subsoil user, but not less than once a year (for wells suspended during drilling, after the completion of drilling, and during operation, where cement plugs have been installed in them) and once a quarter (for wells suspended during operation, where cement plugs have not been installed in them). The results of the inspections are recorded in special logs of any form.
1579. Where deficiencies (wellhead pressure, inter-casing shows, gryphons, and kicks) are detected during inspections or in other cases, the well shall be taken out of suspension. The subsoil user shall determine the causes of the deficiencies and develop and implement actions for their elimination. Further suspension of the well may be extended after the causes of the faults have been eliminated.
1580. Temporary shut-in of wells for economic reasons (pending the construction of the produced fluid gathering and treatment system, the absence of demand for raw material, or the unprofitability of operation) may be carried out without suspension for a period of up to 6 months, with subsequent extension, provided that actions for the safe use of subsoil, the safety of the life and health of the population, and environmental protection are carried out for the duration of the well shut-in.
1581. Where the duration of well suspension has, for whatever reason, exceeded (or may exceed) the design periods or has exceeded 15 years (the period during which the well is idle is not taken into account in this respect), and, based on the results of monitoring its condition (production control, industrial safety review, or state environmental control), a threat of harm to the life and health of people, the natural environment, or property may arise, the subsoil user shall, at the request of the relevant state supervisory and control authority or on its own initiative, develop and implement additional safety measures excluding the risk of accidents, or shall abandon the well in the procedure established by these Rules.
1582. Plates indicating the well number, the field, the time of commencement and termination of well suspension (shut-in), and the subsoil user shall be affixed at the wellhead of suspended and temporarily shut-in wells.
1583. Wells are taken out of suspension on the basis of the subsoil user's work plan.
1584. The suspension of wells during drilling is carried out in the following cases: suspension of a section of the wellbore protected by a casing string, where the work is seasonal in nature - for a period until drilling resumes; destruction of access roads as a result of natural disasters - for the period necessary to restore the roads; the actual geological and technical conditions not corresponding to the design conditions - for a period until the design parameters are clarified and a new (revised) drilling operations project is approved.
1585. The procedure for carrying out the work is established for cases of suspension of open-hole wells and suspension of wells with a run (unperforated) casing string.
1586. For the suspension of open-hole wells, it is necessary to: (a) run drill pipe or tubing down to the bottom of the well, flush the well, and bring the drilling fluid parameters to the values specified in the drilling operations project; (b) pull drill pipe or tubing up to the shoe of the last casing string, and fill the upper part of the string with non-freezing fluid; (c) seal the tubing and annular space of the well; (d) carry out suspension of the drilling equipment; (e) affix a metal or plastic plate at the wellhead indicating the well number, the time of commencement and termination of well suspension, and the owner organisation; where proven or potentially possible sources of MPP are present in the uncased hole interval, their isolation for the suspension period is carried out in accordance with the requirements of paragraphs 1555 and 1556 of these Rules. A cement plug of a height of not less than 20 m is installed in the shoe of the last string.
1587. For the suspension of wells with a run (unperforated) casing string, it is necessary to: (a) run drill pipe or tubing into the well down to the depth of the artificial bottom; (b) treat the drilling fluid, bringing its parameters into conformity with the drilling operations project, and add a corrosion inhibitor; (c) raise the string of pipe 50 m from the bottom, and fill the upper part of the well (0 - 50 m) with non-freezing fluid; (d) carry out further work in accordance with sub-clauses (c) and (d) of paragraph 1589 of these Rules.
1588. All categories of wells are subject to suspension upon completion of drilling, for a period until they are handed over to the customer for the further organisation of oil and gas production, the operation of underground storage facilities, or fields of geothermal, industrial mineral, or medicinal waters, or water injection, in accordance with the design documentation for the construction of the oil, gas and water gathering and treatment system.
1589. For the suspension of wells upon completion of drilling, it is necessary to: (a) kill the well with a fluid treated with corrosion inhibitors having the parameters established by the documentation, and run tubing with a "funnel"; (b) inject special fluid into the perforation interval where necessary, ensuring the preservation of the reservoir properties of the productive formation; (c) install a cement plug in the interval established by the suspension documentation, and pressure-test it at the excess pressure equal to the test pressure of the production casing string; (d) pull the tubing up above the top of the suspension plug (the perforation interval), and fill the upper part of the well with non-freezing fluid; (e) protect the wellhead equipment against corrosion (the method of protection is determined by the suspension work plan); (f) where the pressure anomaly coefficient is equal to or higher than 1.1, include a packer and a shut-off valve in the tubing string, with the tubing left in the well; (g) remove the handwheels and pressure gauges from the wellhead assembly, and install plugs on the assembly; (h) fence off the wellhead (except for wells on cluster pads), affix a plate on the fence indicating the well number, the field, the subsoil user, and the suspension period, and carry out grading around the well pad; (i) the necessity of installing a cement plug above the perforation interval is established by the suspension documentation.
1590. During operation, the following wells are subject to suspension: production wells at oil and gas fields, after the reservoir pressure in them reaches the saturation pressure or the onset of condensation - for a period until reservoir pressures allowing their further operation are restored, as established by the field (deposit) development project; production wells in the event of gas breakthrough from gas caps to the bottom - for a period until workover and isolation work is carried out; production wells where flow rates decline to the values provided for by the field (deposit) development project, and injection wells where injectivity declines - for a period until their conversion or recompletion to another horizon is organised, and until the isolation or subdivision of the operating object for gas (water) injection is carried out in accordance with the field (deposit) development project, or until work to increase injectivity is carried out; production and injection wells in the event of a breakthrough of formation or injected water - for a period until isolation work is carried out, until the front of the injected water is levelled, or until the oil-water contact advances, subject to an opinion of the design organisation; wells whose operation is economically inefficient but may become efficient if the price of oil (gas, condensate, or other products) changes or the taxation system changes, provided that temporary suspension, in the opinion of the design organisation, does not disrupt the field development process; production wells subject to abandonment under Categories 1 - 6, where they may in future be rationally used in the field development system or for other purposes - for a period established by the subsoil user; production wells whose operation has been terminated at the request of state supervisory and control authorities - for a period until the necessary subsoil and environmental protection actions are carried out; Sub-paragraph repealed with effect from 1 September 2023. - Order of Rostechnadzor No. 24 of 31 January 2023; wells subject to workover by sidetracking.
1591. For the suspension of production wells, it is necessary to: (a) pull the equipment out of the well (for suspension of more than 1 year for wells equipped with downhole equipment, the subsurface equipment is pulled); (b) run tubing, flush the wellbore, clean the perforation interval, and, where stuck equipment is present, normalise the bottom up to the top of the stuck equipment; (c) check the tightness of the casing strings and the absence of behind-casing crossflows, and, where leaks or behind-casing crossflows are present, eliminate them with restoration of the bottom, or install and leave cement plugs overlapping 20 m below and above the leak intervals; (d) fill the wellbore with a neutral fluid that excludes corrosive action on the string and ensures the preservation of the reservoir properties of the productive horizon and the necessary back-pressure on the formation, and fill the upper part of the well with non-freezing fluid.
1592. The wellhead assembly configuration, the installation of cement plugs above the perforation intervals, and the possibility of pulling tubing out of the well are established by the well suspension work plan.
1593. The suspension period for wells after operation without the installation of a suspension plug above the perforation interval is 5 years. The suspension period for wells after operation with the installation of a suspension plug above the perforation interval is 7 years. The period during which the well was idle before suspension is not taken into account in this respect. The extension of the well suspension period is established by the subsoil user or its representative.
1594. In wells operating two or more horizons with different reservoir pressures, the necessary isolation of these horizons shall be carried out.
1595. Where the well production contains aggressive components, protection of the casing strings and wellhead equipment against their action shall be provided.
1596. The termination (including early termination) of the suspension of wells suspended during drilling or operation is carried out on the basis of a work plan for taking the well out of suspension. The work plan shall include: the purpose of taking the well out of suspension; the geological and technical characteristics of the well, including information on the conformity of the wellhead equipment with industrial safety requirements; actions for bringing the wellhead equipment into conformity with industrial safety requirements; the geological and technological work assignment; the procedure for carrying out the work; and environmental protection actions. The certificate on taking the well out of suspension is submitted to the territorial office of Rostechnadzor.
1597. When wells are abandoned (with or without a production casing string), the productive formation shall be covered by a cement plug over its entire thickness and 100 m above the top. Where a production casing string has not been run into the abandoned well, a cement plug of a height of not less than 100 m shall additionally be installed in the shoe of the last intermediate string.
1598. In cases of several productive horizons, the isolation of each productive horizon is carried out by a cementing plug installed in the wellbore over its entire thickness, as well as 50 m above the top and 20 m below its base, with preliminary sealing and displacement of high-penetration cementing material into the formation in a volume ensuring the filling of fractures, caverns and voids formed during operation as a result of bottomhole zone treatments (hydraulic fracturing, acid and other treatments), with the formation fluid displaced from the wellbore to a distance of not less than 5 times the initial diameter of the well.
1599. Where, for technical reasons, it is not possible to install a cementing plug in the interval of the productive horizon above the productive horizon, not less than two fluid-tight isolation screens and cementing plugs are installed.
1600. Where secondary deposits, lens-shaped hydrocarbon accumulations, and brine-bearing lenses with abnormally high reservoir pressure are present in the well section, proven by generally accepted methods and techniques during drilling, geophysical survey, testing or operation of the well, work to isolate them is carried out by installing a cement plug in the interval where such a deposit occurs, as well as 50 m above the top and 20 m below its base.
1601. Where stage cementing collars or coupling devices are present in the last string run into the well (production or intermediate), a cement plug shall be installed in the interval of the collars or section coupling, 50 m below and above the coupling point.
1602. Where the well construction includes an abandoned wellbore (wellbores), work is carried out to isolate it (them). In doing so, a fluid-tight seal (in the main wellbore) is created above the sidetrack point of the main working wellbore, in the interval of the cap rock located in its immediate vicinity. Communication between the behind-casing space and the in-casing space is achieved by a technological window in the casing string (strings).
1603. When work is carried out in the interval of the productive formation and other formations whose production contains hydrogen sulphide, the well shall be filled with a treated neutralising drilling fluid of a density ensuring the safe conduct of the work.
1604. The material used for cementing slurries shall be corrosion-resistant and shall comply with the requirements provided for by the drilling operations project for the cementing of casing strings in the intervals of the formation containing hydrogen sulphide.
1605. Slurries used for the installation of cementing seals and screens shall have increased resistance under aggressive media conditions (formation water, brine) and penetrating capacity ensuring penetration into micro-gaps, microfractures and low-permeability formations. In doing so, the set cement shall have fluid-tight properties.
1606. Upon completion of abandonment work, the wellhead shall be equipped with a casing head and a high-pressure valve of corrosion-resistant design, as well as with outlets for monitoring the pressures in the tubing and inter-casing spaces. A fenced pad measuring 2 x 2 m is arranged around the wellhead. A metal plate is installed on the fence, indicating the well number, the name of the field, the subsoil user, the date of completion of drilling, and the inscription "Danger, hydrogen sulphide!".
1607. After abandonment work has been carried out, monitoring of the pressures in the tubing and inter-casing spaces, as well as monitoring of the air around the wellhead and in nearby low-lying areas for hydrogen sulphide content, shall be carried out by the subsoil user or its representative one month later, 6 months later, and thereafter not less than once a year. The results of the measurements are recorded in the relevant certificates.
1608. Where pressure appears at the wellhead, additional isolation work shall be carried out under a special plan agreed with the design organisation and approved by the subsoil user or its representative.
1609. The suspension of wells is achieved by installing cementing plugs. The intervals for installing cementing plugs, the number of plugs, and the requirements for their strength and other properties are determined by the well suspension documentation and the suspension work plans, drawn up taking into account the specific geological and operational characteristics and the initial technical condition of the wells.
1610. When a well is suspended, the perforation interval or open hole is filled with a neutral fluid that does not cause clogging of the productive formation. After the cement plug has been installed, the tubing and annular spaces of the well shall be filled with fluid treated with a neutraliser.
1611. The handwheels of the valves of the wellhead assembly of the suspended well shall be removed, the outer flanges of the valves shall be fitted with plugs, and the pressure gauges shall be removed and the nipples sealed.
1612. The wellhead of a suspended well shall be fenced off, with a plate installed on the fence bearing information on the subsoil user, the field, the well number, and the dates of commencement and termination of suspension, and preserving the legibility of the information for the duration of the well suspension.
1613. When a well (or a section of the wellbore) is abandoned from a drilling rig, blowout preventer equipment (BOP) of the type specified in the drilling operations project shall be used.
1614. The decommissioning of a PT provides for the shutdown of the technical devices and structures of the PT as a whole or of its facilities (hereinafter referred to as PT facilities), with the cessation of the transportation of media, except for the technical devices necessary to ensure the preservation of the shut-down facilities, for a period of 1 to 12 months.
1615. The decommissioning of PT facilities is carried out on the basis of an order of the head of the operating organisation, provided there is a decommissioning action plan for the PT facilities, approved by the technical director of the operating organisation.
1616. The decommissioning action plan for PT facilities shall include: the registration number of the hazardous production facility in the state register of hazardous production facilities, the name, location and general technical characteristics of the PT facilities planned to be decommissioned; the list of work related to bringing the PT facilities into a safe condition; the deadlines for completing the work; periodic monitoring of the condition of the PT during the decommissioning period, taking into account the requirements for technical devices contained in the manufacturers' operating manuals, and indicating the persons responsible for carrying it out; measures ensuring safety; and other actions necessary for carrying out the decommissioning work on the PT facilities and for ensuring compliance with industrial safety requirements.
1617. Completion of the decommissioning action plan for PT facilities is recorded in a certificate of the operating organisation, with an entry made in the PT data sheet. The certificate is kept together with the PT data sheet.
1618. The head of the operating organisation takes the decision to commission the PT, or to suspend or abandon it, not later than 12 months from the date the PT facilities were decommissioned.
1619. The commissioning of PT facilities is carried out on the basis of an order of the head of the operating organisation.
1620. The commissioning of PT facilities for their previous purpose, having been shut down for a period exceeding 3 months, is carried out after trial operation of the PT of not less than 72 hours, and, after 12 months have elapsed, only after revision work has been carried out, provided that the operating period does not exceed the standard period or the period extended on the basis of an industrial safety review.
1621. When a decision is taken to suspend or abandon PT facilities, it is necessary, in addition to the decommissioning action plan for the PT facilities, to carry out: an inspection of the condition of the PT facility (with a frequency established by the operating organisation, but not less than once a year); the release of product and disconnection from operating utilities with the installation of end caps; the treatment (neutralisation, degassing) of equipment and PT that handled toxic substances; and other actions depending on the operating conditions and the technical condition of the PT facilities.
1622. The suspension period for PT facilities is determined by the design organisation but shall not exceed 3 years from the date the decision on suspension is taken.
1623. The suspension documentation shall include actions for taking the PT facilities out of suspension and is subject to an industrial safety review in accordance with the legislation in the field of industrial safety.
1624. The abandonment of PT facilities is carried out in accordance with documentation subject to an industrial safety review.
1625. The abandonment of PT facilities shall be carried out not later than 5 years from the date the decision on abandonment is taken.
1626. During abandonment, the following actions shall be ensured: prevention of environmental pollution; treatment, disposal, decontamination and placement of waste; disposal of equipment and pipe; reclamation of disturbed land; prevention of damage to buildings and structures located within the zone of influence of the facility being abandoned; preservation of the level of anti-corrosion protection of other PT facilities (where the anti-corrosion protection system of the PT or its sections being abandoned participated in forming the anti-corrosion protection system of other PT or their sections); and prevention of the activation of hazardous geological processes (landslides, rockfalls and similar phenomena).
1627. The abandonment of a PT or its facilities is considered complete after the abandonment certificate has been signed.
1628. In the organisation operating a hazardous production facility, or in its oil mines, a service is established whose tasks include ensuring aerological safety.
1629. The organisational and administrative document of the oil mine establishes the list of persons entitled to issue assignments (hereinafter referred to as the work order), the procedure for issuing work orders for carrying out work, and the procedure for admitting employees to carry out work orders. The work order is drawn up in writing.
1630. Issuing a work order for carrying out work in places where there are violations of industrial safety requirements, mining safety requirements, or oil production safety requirements shall be prohibited, except for work to remedy the violations. Where violations of industrial safety requirements, mining safety requirements, or oil production safety requirements are identified, the work is stopped and a separate work order is issued to remedy the identified violations.
1631. The list of high-risk work, the procedure for drawing up permits to work, and the list of employees entitled to issue and approve permits to work are established by the organisational and administrative document of the oil mine. High-risk work at the oil mine is carried out in accordance with instructions establishing the requirements for the organisation and safe conduct of this work, approved by the technical director of the oil mine.
1632. Mine workings, sections, buildings, structures, installations, and technical devices at the oil mine are commissioned in the procedure established by the organisational and administrative document of the oil mine. The operation of faulty mining equipment and faulty technical devices at the oil mine shall be prohibited.
1633. In the separate structural subdivision, the following are organised: recording of employees present in the oil mine, recording of persons who have not come out of the oil mine, and measures for locating them.
1634. The procedure for visiting the mine workings of an oil mine by persons not employed by the organisation operating the hazardous production facility shall be organised in accordance with the administrative document of the oil mine. Persons not employed by the organisation operating the hazardous production facility, before visiting the mine workings of the oil mine, are familiarised with the industrial safety requirements that must be observed when visiting the mine workings of the oil mine and undergo training in the use of the personal protective equipment issued to them. Persons not employed by the organisation operating the hazardous production facility, with the exception of employees of third-party organisations performing work in the mine workings of the oil mine, when visiting the mine workings of the oil mine are accompanied by employees of the organisation operating the hazardous production facility. The lowering of persons into the mine and their presence in underground workings without operational necessity, a work order or the permission of the mine management shall be prohibited. Where the results of calculations establish that the time for evacuation of workers in the event of an accident at the workplaces exceeds the protective action time of the self-rescuer, group storage places for them shall be provided at the mines, ensuring the serviceability and preservation of the self-rescuers. The location of the group storage places shall be approved by the technical manager of the facility and indicated in the plan of actions for the localisation and elimination of the consequences of an accident. The number of self-rescuers at the mine held in the group storage places for isolating self-rescuers at the work sections shall exceed by 10 per cent the largest number of workers of the section per shift. The group storage places for self-rescuers shall be marked, illuminated, known to all persons engaged in underground work and, where necessary, open freely. Workers and technical supervision personnel carrying out work in underground conditions shall be trained in the use of self-rescuers. The checking of workers' knowledge of the rules for the use of self-rescuers shall be carried out by section heads or their deputies at least once every 6 months. Responsibility for the preservation of self-rescuers during their group storage is assigned to the section head, and responsibility for the provision of them - to the head of the facility. The checking of self-rescuers for serviceability shall be carried out quarterly by the head of the dust and ventilation service of the mine (section). The results of the check shall be documented in a report.
1635. By the organisational and administrative document of the oil mine, the mine workings of the oil mine and the ventilation structures, technical devices and pipelines located in them are assigned to the structural subdivisions of the oil mine (hereinafter - the structural subdivision).
1636. The condition of the mine workings of the oil mine is monitored daily by the employees of the structural subdivision. The places where work is carried out in the mine workings of the oil mine are monitored: daily - by the head or the deputy head of the structural subdivision to which these mine workings are assigned; every shift - by the employees of the structural subdivision to which these mine workings are assigned.
1637. The organisational and administrative document of the oil mine determines the mine workings of the oil mine in which a work order for the performance of work is issued to at least two workers having a length of service in the occupation of at least 6 months, one of whom is appointed as the senior. The condition of these mine workings, before workers are directed into them, is checked by the employees of the structural subdivision to which these mine workings are assigned.
1638. When violations of industrial safety requirements are identified during the conduct of mining operations or oil production, measures are taken to eliminate the identified violations. In cases where such violations may lead to the occurrence of an accident or create a threat to the life and health of workers, these operations are suspended, with the exception of the operations to eliminate the violations. Workers not engaged in the work to eliminate the violations proceed to the mine workings in which there are no violations of industrial safety requirements and (or) to the surface.
1639. The procedure for the presence of workers in the mine workings of the oil mine on non-working public holidays is established by the organisational and administrative document of the oil mine. On non-working shifts, for the performance of work in dead-end mine workings, a work order is issued to at least two workers, and the length of service in the occupation of one of them shall be at least 6 months. The conduct of mining operations or oil production operations, after their stoppage for a period of more than one shift, is resumed after a check of the industrial safety condition by the head or an employee of the structural subdivision conducting the mining operations or oil production operations.
1640. Technical devices ensuring the ventilation and air-conditioning of mine workings, water supply, water pumping-out, the lowering and raising of workers and the operation of the MFSB are stopped for the performance of repair work upon the written permission of the technical manager of the oil mine.
1641. Workers engaged in work in the mine workings of the oil mine are provided with certified and serviceable personal protective equipment permanently assigned to them, including isolating-type respiratory protective equipment (hereinafter - self-rescuers), individual battery-powered lamps (hereinafter - cap lamps), gas analysers and (or) alarms for the combustible gases released in the oil mine (hereinafter - individual monitoring devices) and technical devices for location determination, emergency notification, search and detection. Workers conducting work in dead-end mine workings, in mine workings where oil production operations are conducted, and in mine workings with outgoing ventilation currents use individual devices for monitoring the condition of the mine atmosphere. When a group of workers works in one place, group devices for monitoring the condition of the mine atmosphere may be used. Group monitoring devices are not assigned to workers.
1642. All persons performing mining operations or visiting the mine workings of oil mines shall be trained in the rules for the use of self-rescuers and shall undergo training exercises in them in accordance with the procedure established by the organisational and administrative document of the oil mine.
1643. The development of oil fields by the mining method is carried out on the basis of design documentation prepared and approved in accordance with the established procedure. The organisation operating the hazardous production facility organises the preparation, coordination and approval of the plans and schemes for the development of mining operations in accordance with the Rules for the Preparation, Consideration and Coordination of Plans and Schemes for the Development of Mining Operations by Types of Mineral Resources, approved by Government Resolution of the Russian Federation No. 1466 of 16 September 2020 (Collection of Legislation of the Russian Federation, 2020, No. 39, Article 6046).
1644. The documentation for the conduct of mining operations connected with the extraction of rock from the subsoil, the sinking, driving and support of mine workings (hereinafter - the documentation for the conduct of mining operations), and the documentation for the conduct of work on the construction, operation, repair and reconstruction of injection wells and oil production wells, the collection, transport and preparation of heat-transfer medium and oil (hereinafter - the documentation for the conduct of oil production operations) is approved by the technical manager of the oil mine. For each production block, before the start of its construction, the documentation for the conduct of mining operations and the documentation for the conduct of oil production operations are developed. The procedure for the development and the content of the documentation for the conduct of mining operations and the documentation for the conduct of oil production operations is determined by the technical manager of the organisation operating the hazardous production facility. The sections forming part of the documentation for the conduct of mining operations and the documentation for the conduct of oil production operations for a production block may, in the oil mine, be developed in the form of separate documentation for each type of mining operations and oil production operations.
1645. The documentation for the conduct of mining operations and the documentation for the conduct of oil production operations consist of a textual part and a graphical part. The textual part of the documentation contains information on the production block, a description of the adopted technological, technical and other decisions, explanations, references to the regulatory and (or) technical documents used in its preparation, and the calculations and results of calculations substantiating the adopted decisions. The graphical part of the documentation depicts the adopted technological, technical and other decisions, which are executed in the form of drawings, schemes, plans and other documents in graphical form.
1646. The documentation for the conduct of mining operations includes measures to ensure industrial safety and the safe conduct of mining operations.
1647. The documentation for the conduct of oil production operations includes measures to ensure industrial safety and the safe conduct of oil production operations.
1648. The documentation for the conduct of mining operations and the documentation for the conduct of oil production operations shall comply with the design documentation and with the mining-geological and mining-technical conditions. Where the mining-geological and mining-technical conditions change, additions taking into account the changes that have occurred in the mining-geological and mining-technical conditions are introduced into the documentation for the conduct of mining operations and into the documentation for the conduct of oil production operations. The documentation for the conduct of mining operations and the documentation for the conduct of oil production operations, after the introduction of additions into it, is approved by the technical manager of the oil mine.
1649. The documentation for the conduct of mining operations and the documentation for the conduct of oil production operations include technical documentation describing in detail the technological processes, the methods and means of conducting mining operations and oil production operations, the technical means, the technological standards, the conditions and the detailed procedure for carrying out the technological processes (hereinafter - the technological regulations). The technological regulations for the technological processes in the conduct of mining operations are developed in accordance with the industrial safety requirements for the conduct of mining operations and the processing of solid mineral resources.
1650. Workers conducting mining operations are familiarised, against signature, with the documentation for the conduct of mining operations in accordance with which they conduct these operations, and with the technological regulations contained in it.
1651. Workers conducting oil production operations are familiarised, against signature, with the documentation for the conduct of oil production operations in accordance with which they conduct these operations, and with the technological regulations contained in it.
1652. The documentation for the conduct of mining operations and the documentation for the conduct of oil production operations, with the technological regulations contained in them, shall be held in the structural subdivisions performing these operations and by the technical manager of the oil mine.
1653. Accident protection ensures the prevention of accidents and incidents in the mine workings of the oil mine by implementing a set of measures and means determined by the design documentation and, in the event of their occurrence, the conduct of emergency rescue operations.
1654. Before the preparation and approval of the PMLA, by the organisational and administrative document of the organisation operating the hazardous production facility or of its separate structural subdivision, commissions are established to carry out checks of the readiness of the accident protection of the oil mine on the following matters: the provision of the oil mine with emergency exits and their suitability for the movement of persons and the passage of PASF personnel in respirators for the evacuation of casualties; the correspondence of the time for persons to reach a fresh air current to the protective action period of the self-rescuers used, the preparedness of workers to use them, and the possibility of the PASF carrying out its tasks within the protective action time of the respirator; the ventilation devices and structures of the oil mine and the possibility of carrying out the intended ventilation regimes; the reversing, switching and sealing devices of the VGP; the determination of the gassing time of dead-end workings in the event of a stoppage of the VMP; the stability of the ventilation regimes in the mine workings and the reliability of the measures adopted to prevent the spontaneous reversal of ventilation currents; the means of communication and notification of an accident and of searching for persons caught by an accident; the auxiliary emergency rescue units. The results of the checks are documented in reports drawn up in the form established by the organisational and administrative document of the separate structural subdivision.
1655. At least 10 days before the PMLA is put into effect, study of its special section by the workers engaged in work in the mine workings of the oil mine is organised at the oil mine.
1656. In the mine workings of the oil mine and in the above-shaft buildings and structures, a set of systems and means is equipped that ensures the organisation and provision of the safety of the conduct of mining operations and oil production operations. In the mine workings of oil mines, accident protection systems and aerogas protection systems are equipped that ensure the stopping of technical devices where the parameters monitored by these systems exceed the permissible values established by these Rules and the technological regulations. The systems and means of this set are combined into the MFSB.
1657. The technical composition of the MFSB is determined by the design documentation taking into account the hazard analysis and the assessment of the risk of accidents at the hazardous production facility and provides for: aerological safety: a system for monitoring and control of stationary fan installations and the VMP; an AGK system; communication, notification and determination of the location of workers: a system for determining the location of workers in the mine workings of the oil mine; a system for the search for and detection of persons caught by an accident; a system of operational, loudspeaker and emergency underground communication and emergency notification; two independent communication channels with the PASF unit serving the oil mine.
1658. The MFSB shall comply with the requirements in the field of industrial safety and technical regulation, the ensuring of the uniformity of measurements, and the standards for explosion-proof electrical equipment, automated control systems, information technologies, measuring systems and gas-analysis equipment.
1659. The network of active mine workings of the oil mine shall ensure the evacuation of the workers present in them in the event of an accident from the most remote mine workings to the surface and (or) to mine workings with a fresh air current along the routes provided for by the special section of the plan of actions, within the protective action time of the self-rescuers available to him.
1660. For the rescue of workers, PPS are equipped in the underground mine workings of the oil mine. The placement of the PPS in the mine workings of the oil mine is determined by the design documentation approved by the technical manager of the organisation, taking into account the provision of an additional possibility of self-rescue of workers wearing self-rescuers along the routes of their travel from the place of work to the surface.
1661. At the places of the mine workings of the oil mine determined by the plan of actions, signboards with the names of the mine workings, indicators of the direction of movement to the PPS and to the emergency exits to the surface, safety signs and signalling devices are installed. Signboards with the names of the mine workings and indicators of the direction of movement are illuminated or made using light-reflecting materials and are installed at all junctions of the mine workings.
1662. The equipping of the PPS with individual and collective protective equipment and first-aid means, and also the arrangement of the monitoring of their condition and the procedure for their replacement and servicing, are determined by the design documentation, which is developed taking into account the maximum number of workers proceeding to the PPS in the event of an accident along the routes provided for by the plan of actions.
1663. The arrangement of the PPS in the mine workings of the oil mine is indicated in the graphical material of the special section of the PMLA.
1664. The conduct of mining operations without the documentation for the conduct of mining operations approved by the head of the oil mine shall be prohibited.
1665. During the development of oil fields by the underground method, work is carried out to identify the propensity of rocks to gas-dynamic and geodynamic phenomena. At oil fields with rocks prone to dynamic phenomena, geodynamic zoning is carried out during the development of the design documentation.
1666. Mining operations are performed by at least two workers, and the length of service in the occupation of one of them shall be at least 6 months.
1667. The conduct of mining operations by workers of a structural subdivision of the organisation or of a contractor organisation in mine workings assigned to another structural subdivision is coordinated with the head of that structural subdivision.
1668. In the active mine workings of the oil mine, at least two exits, unobstructed by anything, are provided for.
1669. From dead-end workings and from the places where repair work is carried out in the active mine workings, an exit to the nearest mine workings is ensured.
1670. At each active oil mine there shall be at least two exits to the surface equipped for the movement and (or) transport of persons. Each level of the oil mine shall have at least two exits to the level above and (or) the level below or to the surface, equipped for the movement (transport) of persons.
1671. In mine workings equipped for the movement (transport) of persons to the surface and (or) from level to level, different directions of movement of the ventilation currents are ensured.
1672. Two or more parallel workings along which the ventilation current, during emergency ventilation regimes of the oil mine, moves in one direction constitute one emergency exit.
1673. The condition of the mine workings serving as emergency exits is checked at least once a month by the persons appointed by the organisational and administrative document of the oil mine. The results of the check are recorded in the register for recording the results of inspections of the support and the condition of the mine workings, drawn up in the form established by the organisational and administrative document of the oil mine, and in the register for recording the results of inspections of the condition of the mine shafts, drawn up in the form established by the organisational and administrative document of the oil mine.
1674. Vertical and inclined mine workings that are exits to the surface are equipped with technical devices ensuring the transport of persons and (or) with ladder compartments.
1675. In the case of a central location of two or more vertical and (or) inclined mine workings driven to the same level: the ladder compartment in one of these workings may be absent, provided that two technical devices ensuring the transport of persons with an independent supply of electrical energy are installed in it; in shafts up to 70 m deep, the technical device ensuring the transport of persons is not installed in one of them, provided that both shafts have ladder compartments.
1676. Mine workings coming out to the surface, at the mouth of which the permanent presence of workers is not provided for, are equipped with devices ensuring exit from the oil mine and preventing access to them from the surface, with means of communication and with signalling led out to the mine dispatcher of the oil mine.
1677. Inclined mine workings intended for the movement of persons are equipped, at angles of inclination: from 7° to 10° - with gangways; from 11° to 25° - with gangways with handrails; from 26° to 30° - with walkways with steps and handrails; from 31° to 45° - with stairways with horizontal steps and handrails; more than 45° - with ladder compartments.
1678. Ladders in ladder compartments are installed at an angle of not more than 80°. The width of the ladders shall be at least 0.4 m, and the distance between the rungs - not more than 0.4 m. The distance between the support of the mine working and the ladder at its base shall be at least 0.6 m. In the ladder compartments, horizontal platforms are installed at intervals of not more than 8 m. The ladders shall project at least 1 m above the horizontal platforms. In the horizontal platforms, for free passage, manholes at least 0.6 m wide and at least 0.7 m high are provided. The manholes above the first upper ladder are closed with trap doors.
1679. In inclined mine workings that are exits from level to level or to the surface, along which the delivery of loads and workers is carried out, at the sections where the lower and intermediate receiving landings are equipped, bypass workings are driven.
1680. Passages for persons in the mine workings of the oil mine shall be at least 0.7 m wide at a height of 1.8 m. The passages are marked with indicators.
1681. The driving and support of mine workings are carried out in accordance with the design documentation, the TR and the documentation for the conduct of mining operations.
1682. The minimum cross-sectional areas of horizontal and inclined mine workings in the clear are given in Appendix No. 12 to these Rules. The width of the passages for persons and the size of the clearances between the support, equipment, pipelines and rolling stock are given in Appendix No. 13 to these Rules.
1683. In oil mines of hazard groups I and II in respect of hydrocarbon gases, mine workings along the productive formation or at a distance of less than 5 m from it are driven with the drilling, along the axis of the working, of an exploratory borehole or a shot hole at least 3 m long.
1684. The lag of the permanent support behind the faces of development workings shall be not more than 3 m. The section of the mine working from the face to the permanent support is supported with temporary support. At the start of a new cycle, the permanent support shall lag behind the face by a distance of not more than the support installation step. The presence of persons in the unsupported part of the working shall not be permitted. In stopped workings, the permanent support is installed right up against the face.
1685. During the driving, support and repair of mine workings, measures are taken to exclude the formation of voids in the supported space. Any voids that form are packed or grouted.
1686. The holing-through of mine workings is conducted in compliance with the measures ensuring industrial safety and the safety of the conduct of mining operations approved by the technical manager of the oil mine.
1687. The use of the support of a mine working as a bearing structure shall not be permitted, with the exception of the suspension of ventilation pipes, the cable network, pipelines, technical devices and their elements.
1688. From dead-end mine workings being driven, the simultaneous driving of other dead-end mine workings shall be prohibited.
1689. Workers conducting work on the driving of raises are provided with gas detectors for the rapid determination of the concentrations of oxygen O2, carbon monoxide CO, carbon dioxide CO2, methane CH4, and nitrogen oxides NO, NO2.
1690. The performance of work on the erection of temporary and permanent support from platforms mounted on mining equipment and vehicles shall not be permitted.
1691. It shall not be permitted to perform work on the equipping of vertical mine workings without a fall-arrest system, or to use suspended cradles as a hoisting conveyance.
1692. The inspection of the support and equipping of vertical mine workings is carried out at a frequency of at least once a week in accordance with the procedure established by the organisational and administrative document of the oil mine.
1693. After the completion of work on the repair of the support or the equipping, the vertical mine working is inspected by a person appointed by the technical manager of the oil mine, and the lowering and raising of the hoisting conveyance is carried out in it, with the entering of the results of the inspection into the register for recording the results of inspections of the condition of the mine shafts.
1694. The performance of work on the driving, support and repair of a vertical mine working during the movement of hoisting conveyances along it shall not be permitted.
1695. The driving of a vertical mine working after the support of its mouth without a covering at the zero mark and without a safety platform shall not be permitted.
1696. Workers conducting work in a vertical mine working are protected from objects falling from above. During the deepening of a vertical mine working, a safety platform is installed or a pillar is left between its face and the operating hoists.
1697. In vertical mine workings, during the performance of work on the installation or dismantling of flexible concrete pipelines, the simultaneous performance of work on driving, support and equipping shall not be permitted.
1698. At the sections of mine workings equipped with rail transport where shunting operations and the coupling and uncoupling of trains are carried out, at the stationary loading points and in the shaft-bottom workings of the cage shaft, clearances for the passage of persons are provided on both sides of the rail tracks. The arrangement of passages between the rail tracks shall not be permitted. The clearance for the passage of persons at the sections of mine workings where the boarding of persons into passenger trains is carried out shall be at least 1 m on the boarding side.
1699. In the upper and lower parts of inclined mine workings equipped with rail transport, guarding devices are installed at a distance of not more than 20 m from the junctions and, in the case where mining operations are conducted in the given working, at a distance of not more than 20 m from the place of their conduct.
1700. The cross-sections of the active mine workings shall comply with the design documentation.
1701. The re-support of the junctions of mine workings is carried out under the direct supervision of an employee of the structural subdivision conducting these operations.
1702. Work on the elimination of blockages in mine workings is carried out in compliance with the measures ensuring industrial safety and the safety of the conduct of mining operations approved by the technical manager of the oil mine.
1703. In the roof and sides of unsupported mine workings or workings supported with anchor support, the presence of detached pieces of rock shall not be permitted.
1704. The profiling of the guides and walls of the main vertical mine shafts is carried out at least once a year, and of the auxiliary mine shafts - at least once every 2 years.
1705. Checks of the condition of the shaft support and the space behind the support are carried out at least once every 2 years by a commission whose composition is determined by the organisational and administrative document of the oil mine. The results of the checks are entered into the register for recording the results of inspections of the condition of the mine shafts.
1706. Work on the capital repair of mine workings or sections of them in difficult conditions (in the zone of loose deposits, in alluvial deposits, in the presence of quicksands, at thawed sections in permafrost rocks), and work on the repair and elimination of the consequences of accidents, are carried out in compliance with the measures ensuring industrial safety and the safety of the conduct of mining operations approved by the technical manager of the oil mine.
1707. Work on the re-support of vertical mine workings is carried out from a fixed stationary or suspended platform. On the platform, a suspended ladder to the platform of the ladder compartment is provided for.
1708. In a vertical mine working, below the place where repair work is carried out, a safety platform is installed. At a height of not more than 5 m from the place where repair work is carried out, a safety covering is installed.
1709. Work on the re-support of vertical mine workings is carried out under the direct supervision of an employee of the structural subdivision to which these mine workings are assigned.
1710. The simultaneous conduct of repair work in a mine working with an angle of inclination of 18° or more at two or more places shall not be permitted. Work on the re-support of shafts and inclined workings with an angle of inclination of 18° or more is carried out in separate sections. Before the dismantling of the old support at the section where work is carried out, temporary support is installed, and the permanent support located above and below the support being dismantled is reinforced with temporary support.
1711. When repair work is carried out in vertical and inclined mine workings, the raising and movement along them of persons not engaged in the repair work shall not be permitted.
1712. The repair of inclined haulage workings with endless-rope haulage may be performed only when the rope is free of mine cars. It is permitted to leave mine cars intended for the repair of the working, provided that they are securely fastened so as to exclude spontaneous movement and, in workings with tail-rope haulage, additionally, that they are attached to the traction rope.
1713. During the re-support of a working, it shall not be permitted to remove more than two support frames simultaneously. During the re-support of horizontal workings with locomotive haulage, light signals are placed at a distance of the braking distance, but not less than 80 m, on both sides of the place of work.
1714. During the clearing of blockages and the restoration of mine workings, the ventilation of the places where work is carried out and the continuous monitoring of the parameters of the mine atmosphere are ensured.
1715. Work on the repair of mine workings in which there is a danger of a breakthrough of the heat-transfer medium is carried out in compliance with the measures ensuring industrial safety and the safety of the conduct of mining operations approved by the technical manager of the oil mine.
1716. After the elimination of a breakthrough of the heat-transfer medium or of hot liquids and vapours into the working, the support at the place of the breakthrough is checked and, where necessary, reinforced. Cases of breakthroughs of the heat-transfer medium into mine workings, and also the measures taken to eliminate the breakthroughs and their consequences, are recorded in the register for recording the results of inspections of the support and the condition of the workings.
1717. In active haulage workings, annually and after their capital repair, a check of the clearances between the sides of the working and the rolling stock is carried out.
1718. On the rail tracks at vertical mine workings equipped with cage hoisting installations, closed arresting stops or other devices are installed that exclude the presence of mine cars in front of the vertical mine working in the absence of the cage.
1719. In front of the mouths of vertical mine workings equipped with trap doors, guards are installed at the lower and upper receiving landings. In the absence of a mechanical drive for opening the trap doors, the work is performed with the use of a fall-arrest system.
1720. The mouths of vertical mine workings not equipped with a hoist, and also of boreholes, are supported above the surface by at least 0.5 m and are covered with trap doors or gratings. The doors or gratings at vertical mine workings are closed during the movement of the hoisting conveyance or during the time of its stoppage at the intermediate levels.
1721. Vertical mine workings and wells with an inclination angle of more than 25° are fenced off or covered.
1722. The ladder compartments of vertical mine workings are fenced off with a plank or metal partition.
1723. Access to the mouths of vertical mine workings is provided through doors that are locked with a lock. Lattice doors installed at the junctions of vertical mine workings with horizontal or inclined workings are locked with a lock. If the ventilation shafts of the mines and the pits serve as emergency exits, the above-mentioned lattice doors are fastened with latches without locks, and the doors at their mouths - with latches that open from the inside without a key. The lattice doors are closed after people have passed through.
1724. The abandonment and conservation of the mine workings of oil mines are carried out in accordance with the documentation for the abandonment and conservation of mine workings.
1725. The abandonment and conservation of wells drilled from the surface are carried out in accordance with the requirements of Chapter LVIII of these Rules.
1726. The mouths of abandoned mine workings that have an outlet to the earth's surface are inspected at least 2 times a year by a commission whose composition is determined by the organisational and administrative document of the oil mine.
1727. Work on the extraction of support from horizontal and inclined mine workings is classified as high-hazard work and is carried out in accordance with the mining operations documentation.
1728. Mine workings being abandoned that have an outlet to the surface (shafts, pits, adits, wells with a diameter of 200 mm and more) are completely filled with non-combustible materials (with the exception of clay). After this, the mouths of vertical mine workings are covered with reinforced-concrete decks or decks made of metal beams or rails, and the mouths of inclined and horizontal workings are closed with brick, stone or concrete stoppings. For the period of abandonment of these workings, their mouths are fenced off. Mine workings being abandoned are isolated from the workings adjacent to them.
1729. The extraction of support from the shafts of oil mines and other vertical workings, as well as from inclined workings with an inclination angle of more than 30°, shall not be permitted. The extraction of support from horizontal and inclined workings with an inclination angle of not more than 30° is carried out using mechanisms and with closing of the working in a direction ensuring an exit to the shaft of the oil mine. The extraction of support in inclined workings with an inclination angle of from 15° to 30° is permitted to be carried out in a direction from the bottom upwards.
1730. At oil mines adjacent to oil mines being abandoned or conserved, mining operations are carried out in compliance with measures ensuring the safety of their conduct.
1731. The concentration of oxygen in the air in the mine workings of oil mines shall be at least 20 per cent (by volume). The maximum permissible concentration of carbon dioxide in the mine air is: in the return currents of dead-end mine workings and mine workings where drilling and operation of wells are carried out - 0.5 per cent; in mine workings with a return current of a wing, horizon or mine - 0.75 per cent; in dead-end mine workings ventilated through a cave-in, during their driving and restoration - 1 per cent. The maximum permissible concentration of hydrogen in charging chambers is 0.5 per cent. The maximum permissible concentrations of carbon monoxide, nitrogen oxides, sulphur dioxide, hydrogen sulphide (harmful gases) and hydrocarbons (C1 - C10) in the mine atmosphere of the mine workings of oil mines are given in Appendix No. 14 to these Rules.
1732. Oil mines in which methane, ethane, propane, butane (hereinafter - hydrocarbon gases) and vapours of the liquid hydrocarbons pentane, hexane, heptane, octane and nonane (hereinafter - vapours of liquid hydrocarbons) have been detected, or the release of which is predicted, are classified as gas-hazardous oil mines. In the mine workings of gas-hazardous oil mines, the gas regime is observed.
1733. The maximum permissible total concentrations of hydrocarbon gases and vapours of liquid hydrocarbons in the mine atmosphere of gas-hazardous oil mines are given in Appendix No. 15 to these Rules.
1734. The monitoring of the composition of the mine air and the determination of the gas abundance of gas-hazardous oil mines are carried out in accordance with Appendix No. 15 to these Rules.
1735. Depending on the total content of ethane, propane, isobutane and butane (hereinafter - higher hydrocarbon gases) released into the mine atmosphere, gas-hazardous oil mines are classified: as hazard group I for hydrocarbon gases - where the content of higher hydrocarbon gases in the total volume of hydrocarbon gases is not more than 10 per cent (by volume); as hazard group II for hydrocarbon gases - where the content of higher hydrocarbon gases in the total volume of hydrocarbon gases is more than 10 per cent (by volume).
1736. In mines of hazard group II, the total content of higher hydrocarbon gases in the mine atmosphere shall not exceed half the lower explosive limit of the heaviest of them: where ethane is present in the mixture - 1.4 per cent by volume; ethane and propane - 1.0 per cent by volume; ethane, propane and isobutane - 0.9 per cent by volume; ethane, propane, isobutane and butane - 0.8 per cent by volume.
1737. The classification of oil mines into hazard groups for hydrocarbon gases is carried out: for oil mines under construction - in accordance with the design documentation, based on the results of determining the natural gas content during geological exploration work; for operating oil mines - based on the results of monitoring the composition of the mine air and determining the gas abundance of the oil mines, carried out in accordance with Appendix No. 16 to these Rules.
1738. If the maximum permissible concentrations of carbon dioxide and (or) harmful gases are exceeded in active mine workings, work is stopped, and the workers leave these mine workings for mine workings with a mine atmosphere fit for breathing or go to the surface and report this to the mine dispatcher of the oil mine.
1739. When developing oil fields or sections of them containing free hydrogen sulphide, measures to prevent the effect of hydrogen sulphide on people, the occurrence of pyrophoric phenomena, and corrosion of equipment and pipelines are included in the mining operations documentation and the oil production operations documentation.
1740. If, in active mine workings, the maximum permissible concentrations of hydrocarbon gases and vapours of liquid hydrocarbons are exceeded (hereinafter - gas contamination), mining operations are stopped, the voltage is switched off from the electrical equipment, with the exception of mining special-explosion-proof electrical equipment, the workers leave these mine workings for mine workings with a mine atmosphere fit for breathing or go to the surface and report this to the mine dispatcher of the oil mine. In gas-contaminated mine workings, notice boards are installed with information about the gas contamination of these workings. The list of workers involved in carrying out work on gas clearing of mine workings and in investigating the causes of gas contamination that has occurred is determined by written order of the technical manager of the oil mine. Gas clearing of mine workings, and the investigation, recording and prevention of gas contamination, are carried out in accordance with Appendix No. 17 to these Rules.
1741. When local accumulations of hydrocarbon gases and vapours of liquid hydrocarbons with concentrations exceeding their maximum permissible concentrations form at drilling rigs and mining combines, the operation of the drilling rigs and mining combines is stopped, and the voltage is switched off from the supply cable. The operation of the drilling rigs and mining combines is resumed after the concentration of hydrocarbon gases and vapours of liquid hydrocarbons in the local accumulations is reduced to permissible values.
1742. In the event of the appearance in the mine workings of blower emissions of hydrocarbon gases and vapours of liquid hydrocarbons, work in these workings is carried out in accordance with the TR.
1743. The ventilation of the oil mine is carried out in such a way that all active mine workings are provided with an air flow rate calculated from the total release into them of hydrocarbon gases and vapours of liquid hydrocarbons (hereinafter - the calculated air flow rate).
1744. The air velocity in the mine workings of oil mines shall be at least 0.25 m/s, and in mine workings less than 30 m long - at least 0.1 m/s.
1745. The maximum permissible air velocities in the mine workings of oil mines are given in Appendix No. 18 to these Rules. Work in mine workings in which the air movement velocity exceeds the maximum permissible velocities is carried out in accordance with the technological regulations.
1746. The air temperature in production, development and other active workings near places where people work shall not exceed 26 °C at a relative humidity of up to 90 per cent and 25 °C - at a relative humidity of more than 90 per cent.
1747. In mine workings in which the injection of a heat carrier into the stratum or the extraction of production from producing wells is carried out, in which pipelines with an outer surface temperature of 40 °C and above are laid (hereinafter - "hot" pipelines), as well as in oil-trap tanks, a mine-atmosphere temperature of up to 36 °C inclusive is permitted, provided that people are not continuously present in these mine workings during the work shift. The mode of operation providing for breaks in specially equipped places with a mine-atmosphere temperature and humidity conforming to paragraph 1746 of these Rules is included in the mining operations documentation and the oil production operations documentation for these workings.
1748. The visiting of mine workings in which the temperature and humidity of the mine atmosphere exceed the values established in paragraph 1746 of these Rules, and work in them, shall be carried out by at least two workers.
1749. The temperature of the air entering the oil mines shall be at least 2 °C at a distance of 5 m from the junction of the air-heater channel with the shaft. The use of fire air heaters shall not be permitted.
1750. To distribute air through the mine workings of oil mines under normal and emergency ventilation modes, ventilation devices are installed. Ventilation devices include airlocks, crossings and isolation stoppings. The designs of ventilation devices are approved by the technical manager of the oil mine. The dimensions of the door openings of ventilation devices shall ensure distances from the transported load to their elements of at least 0.5 m in height and at least 0.25 m in width. A notice board indicating its number is installed on each ventilation device. Unused ventilation devices are dismantled.
1751. In mine workings connecting workings with fresh and return ventilation currents, airlocks or crossings are arranged. The ventilation devices in these workings are made of non-combustible materials and have an interlock preventing the simultaneous opening of the doors, which would lead to short-circuiting of the ventilation current, or are equipped with sensors for the simultaneous opening of the doors that signal the fact of the simultaneous opening of the doors to the mine dispatcher of the oil mine.
1752. An airlock is made of at least two ventilation stoppings. The stoppings in the airlock have main and reversing doors or trap doors that open in opposite directions. The main and reversing doors are made self-closing and are kept in the closed position. Leaving the main and reversing doors and trap doors in the open position shall not be permitted.
1753. Where the pressure differential across a ventilation device is more than 50 daPa, the ventilation doors are equipped with devices that facilitate their opening.
1754. The installation of ventilation structures shall not be permitted in inclined mine workings along which the delivery of loads and the transport of workers are carried out by floor-mounted rail transport not equipped with emergency braking devices. The passage of liquid through a stopping is carried out through a siphon, the depth of which in millimetres shall be at least the pressure differential across this stopping, measured in millimetres of water column. Accumulations of oil that have formed at the stoppings are eliminated. The procedure for monitoring ventilation devices by workers of the aerological safety service is established by the organisational and administrative document of the oil mine. The results of the monitoring are entered in the log for registering and recording the results of inspection of the condition of ventilation stoppings, airlocks and crossings, drawn up in the form established by the organisational and administrative document of the oil mine.
1755. The direction of air movement in the mine workings and its flow rate shall comply with the design documentation. The regulation of the air flow rate in the mine workings of the oil mine is carried out by decision of the head of the aerological safety service, agreed with the technical manager of the oil mine. Shift-by-shift regulation of air currents shall not be permitted.
1756. The ventilation of the mine workings of the oil mine is provided by continuously operating VGP and VVU installed on the surface at the mouths of hermetically sealed shafts, pits, adits and wells. The distance from the VGP buildings to the mouths of the shafts, pits, adits and wells is established by the design documentation. The VGP provide ventilation of the mine workings of the entire oil mine or a part of it (a block, wing, panel, horizon), as well as ventilation of the oil mine during the period of its construction after the holing of the shafts. The VVU provide ventilation of sections, blocks and (or) individual mine workings of the oil mine. The service life of the VVU is established by the manufacturer and is specified in the operational documentation.
1757. The VGP and VVU consist of working and standby units. The working and standby units shall be of the same size and type. The VGP and VVU provide a supply of air to the mine of not less than the calculated flow rate. The flow rate of air entering the mine workings when switching from the working to the standby fan shall not change by more than 10 per cent.
1758. In the VGP and VVU, automatic start-up of the standby fan when the working fan stops is provided. The fans are equipped with braking or locking devices that prevent spontaneous rotation of the fan's working rotor.
1759. In the VGP and VVU, measures are provided to prevent icing of the flow path of the fans, channels and switching devices, as well as measures to prevent rock mass and water from entering the flow path of the fan installation. The placement of foreign objects in the ventilation channels shall not be permitted. The ventilation channels are equipped with an airlock exit to the surface. In the channel of the VGP and VVU, at the junction with the shaft (pit, well) and in front of the fan wheel, guard gratings at least 1.5 m high are installed.
1760. The VGP and VVU provide the emergency ventilation modes of the oil-mine workings provided for by the action plan. Scheduled practical checks of the emergency ventilation modes provided for by the PMLA at the hazardous production facility (oil mine), developed by the organisation operating the hazardous production facility or by its separate structural subdivision in accordance with the requirements established for the hazardous production facility (oil mine), are carried out in the manner given in Appendix No. 19 to these Rules. During a scheduled practical check of the emergency ventilation modes provided for by the action plan, it shall not be permitted to carry out any work in the oil mine other than work to maintain the life support of the oil mine. The switching of the VGP to reverse operating mode is carried out in no more than 10 minutes. In the event of accidents, the air flow rate in the reverse ventilation mode passing through the mine workings in which the action plan provides for reversal of the ventilation current shall be at least 60 per cent of the air flow rate passing through them under the normal ventilation mode. The total content of hydrocarbon gases and vapours of liquid hydrocarbons shall not exceed: in mine workings with ventilation currents returning from the oil mine and section ventilation currents, under the reverse ventilation mode carried out for two hours - 35 per cent of the lower concentration limit of flame propagation of the monitored mixture (hereinafter - the LCLFP of the mixture) or 1.5 per cent (by volume) - in oil mines of hazard group I for hydrocarbon gases, 1.2 per cent (by volume) - in oil mines of hazard group II for hydrocarbon gases; in places where a fire may occur - 45 per cent of the LCLFP of the mixture or 2 per cent (by volume) - in oil mines of hazard group I for hydrocarbon gases, 1.6 per cent (by volume) - in oil mines of hazard group II for hydrocarbon gases.
1761. The serviceability of the reversing, switching and sealing devices of the VGP is checked by the chief mechanic of the oil mine and the head of the aerological safety service at least 1 time a month. The condition of the VGP and VVU is checked: daily - by the workers servicing the fan installations; at least 2 times a month - by the chief mechanic of the oil mine and (or) a worker designated by him. The procedure for carrying out checks of the condition of the VGP and VVU is determined by the chief mechanic of the oil mine. The results of the checks are entered in the log for inspection of fan installations and checking of reversal, drawn up in the form established by the organisational and administrative document of the oil mine. An aerodynamic survey of the VGP and VVU is carried out by workers of the aerological safety service when switching from one unit to another and when changing the angle of rotation of the blades of the impellers or of the guide vane assembly. The switching from one unit to another is carried out at least 1 time a month. The overhaul, adjustment and aerodynamic survey of the VGP and VVU are carried out in accordance with the manufacturer's operational documentation.
1762. The VGP and VVU are equipped with remote control and monitoring equipment in accordance with the MFSB design. The VGP and VVU not equipped with remote control and monitoring equipment are continuously serviced and monitored by an operator on duty. The operating parameters of the VGP and VVU are recorded by the operator on duty in the manner established by the organisational and administrative document of the oil mine. The building of the VGP and VVU is equipped with communication with the mine dispatcher of the oil mine. All changes to the operating modes of the VGP and VVU are recorded by the mine dispatcher of the oil mine.
1763. The power supply circuits of the working and standby units of the VGP are made independent and containing no common elements the failure of which may cause loss of control or shutdown of both units.
1764. Where a fan installation is remotely controlled, the building of the fan installation is kept closed. In the building of the fan installation, and for automated fan installations also in the room of the mine dispatcher of the oil mine, the following are posted: the procedure for switching the fan installation to reverse mode, the power supply circuit, the individual characteristics of the fans, and the instruction for the operator (the mine dispatcher). The log for recording the operation of fan installations, drawn up in the form established by the organisational and administrative document of the oil mine, is kept by the operator of the fan installation, and for automated fan installations - by the mine dispatcher of the oil mine.
1765. Stops of the VGP and VVU (except emergency stops) and changes to their operating mode are carried out by written order of the technical manager of the oil mine or the person acting in his place.
1766. The merging of oil mines with independent ventilation into a single ventilation system is carried out in accordance with the design documentation.
1767. The ventilation plans of oil mines are drawn up annually by the head of the aerological safety service during the preparation of the plan (production programme) for the development of mining operations. The procedure for drawing up the ventilation plans of oil mines is given in Appendix No. 20 to these Rules. At least once every 3 years, a scheduled depression survey is carried out at the oil mine. The conduct of unscheduled depression surveys is determined by the technical manager of the oil mine.
1768. It shall be prohibited to use the same shaft of an oil mine for the simultaneous passage of fresh and return air currents. This prohibition does not apply during the sinking of shafts and near-shaft workings.
1769. Chambers for charging accumulator batteries and stores of explosive materials, as well as all tanks of the central oil traps and the sumps of the GVU, are ventilated by a separate current of fresh air. Chambers for machines and equipment, garages and stores of fuel and lubricants, and mine workings in which the maintenance of diesel transport is carried out are ventilated by a separate current of fresh air or by a current of return air in which the total concentration of hydrocarbon gases does not exceed 10 per cent of the LCLFP of the mixture or 0.5 per cent (by volume) - in oil mines of hazard group I for hydrocarbon gases, 0.4 per cent (by volume) - in oil mines of hazard group II for hydrocarbon gases. It is permitted to ventilate by diffusion the electrical-machine and transformer chambers having a depth (length) of up to 6 m, driven through barren rock or through a degassed oil-bearing stratum and supported with monolithic concrete lining or shotcrete.
1770. It shall not be permitted to ventilate active mine workings through cave-ins and collapses. This requirement does not apply to work on the localisation and elimination of the consequences of accidents or to work on the closing and restoration of mine workings and work on clearing cave-ins. VMP are used in cases where, when carrying out work on the closing and restoration of mine workings and work on clearing cave-ins, it is impossible to provide ventilation by the general-mine depression.
1771. Work in faces approaching mine workings in which accumulations of harmful or combustible gases are possible, and the opening of such workings, are carried out in compliance with measures ensuring industrial safety and the safe conduct of mining operations, approved by the technical manager of the oil mine.
1772. Unused mine workings are isolated. The isolation of unused mine workings is carried out in accordance with the isolation documentation approved by the technical manager of the oil mine. Electrical equipment and electrical cables are removed from the isolated mine workings. The time and places of erection, as well as the designs of the structures isolating the unused mine workings, are approved by the technical manager of the oil mine. The isolation of mine workings with active injection or producing wells is permitted in cases where, in these workings, the supply of a heat carrier to the injection wells and the collection and removal of production from the producing wells are carried out in accordance with the technological regulations.
1773. Mine workings whose operation has been completed are isolated, and all wells in them are abandoned.
1774. The opening of stoppings and the gas clearing of isolated mine workings are carried out by staff of the PASF in accordance with a developed technological regulation agreed with the commander of the PASF unit servicing the oil mine.
1775. The ventilation of dead-end mine workings of oil mines is carried out by continuously operating VMP or by the general-mine depression. The ventilation of dead-end mine workings by the general-mine depression is permitted where the length of partitions or ventilation ducts is not more than 60 m. The ventilation of dead-end mine workings up to 6 m long by diffusion is permitted. In gas-hazardous oil mines, dead-end mine workings ventilated by VMP are equipped with standby VMP and standby power supply. The standby fan is connected to the ventilation duct and is automatically switched on when the working fan stops. It is permitted not to equip with standby VMP the dead-end mine workings in which the release of hydrocarbon gases and vapours of liquid hydrocarbons has not been detected.
1776. In gas-hazardous oil mines, automatic monitoring of the operation and control of electrically driven VMP is organised. The control means for the VMP shall ensure their continuous operation and the possibility of controlling the VMP from the place of their installation and from the workstation of the AGK operator and (or) the mine dispatcher of the oil mine. Continuous ventilation of dead-end mine workings and the performance of the functions of the AGK systems are ensured before their driving begins. In the event of a VMP stopping, work in the dead-end part of the working is stopped, the voltage is removed from the electrical equipment, and people are led out of it into a ventilated working.
1777. Calculations justifying the choice of VMP, and graphic documentation containing layouts of the placement in the mine workings of the oil mine of the VMP and technical devices ensuring ventilation of the mine working and operation of the VMP, are included in the mining operations documentation or the oil production operations documentation for mine workings ventilated by VMP. A VMP operating in forcing mode is installed in a mine working with a fresh-air current at a distance of at least 10 m from the return current. The actual capacity of a VMP shall not exceed 70 per cent of the air flow rate in the mine working at the place of its installation. Where several VMP operating on separate ventilation ducts and located less than 10 m from one another are installed in a single mine working, their total capacity shall not exceed 70 per cent of the air flow rate in the mine working at the place of installation of the first VMP, counting along the direction of the current. If the distance between the VMP is more than 10 m, the capacity of each of the VMP shall not exceed 70 per cent of the air flow rate in the mine working at the place of its installation. The ventilation of two or more mine workings by means of a single ventilation duct with branches shall not be permitted. It is permitted to install a VMP in a mine working with a return-air current, provided that the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons in this working does not exceed 10 per cent of the LCLFP of the mixture or 0.5 per cent (by volume) - in oil mines of hazard group I for hydrocarbon gases, 0.4 per cent (by volume) - in oil mines of hazard group II for hydrocarbon gases, the composition of the mine atmosphere conforms to the requirements of paragraph 1731 of these Rules, and a stationary sensor of the AGK system monitoring the parameters of the mine atmosphere is installed in front of the VMP.
1778. In front of a VMP, a notice board is installed containing data on the actual air flow rate in the mine working at the place of installation of the VMP, on the actual capacity of the fan, on the calculated and actual air flow rates at the face of the dead-end mine working, on the maximum length of the dead-end part of the mine working ventilated by this fan installation, on the ventilation time of the mine working after blasting operations, the date of completion of the notice board, and the signature of the oil-mine worker who carried out the measurements.
1779. The distance from the end of the ventilation duct to the face shall not exceed 8 m, and when driving raise workings - not more than 6 m. The ventilation duct is maintained in a condition ensuring the calculated air flow rate at the face.
1780. Fan installations ventilating vertical mine workings driven from the surface are installed at distances of not less than 15 m from the mouths of these workings. The distance from the end of the ventilation pipes to the face of a vertical mine working ventilated by a fan installation shall be not more than 15 m, and during loading by grab - not more than 20 m. The ventilation pipes are suspended on ropes or fastened to the support of the working.
1781. The ventilation of dead-end mine workings is organised in such a way that the ventilation currents returning from them do not enter mine workings in which the injection of a heat carrier into the stratum and (or) the extraction of production from producing wells are carried out. The air current returning from a development mine working is permitted to be discharged into mine workings with a fresh-air current ventilating mine workings in which the injection of a heat carrier into the stratum and (or) the extraction of production from producing wells are carried out, provided that in the ventilation currents entering these workings: the total concentration of hydrocarbon gases does not exceed 10 per cent of the LCLFP of the mixture or 0.5 per cent (by volume) - in oil mines of hazard group I for hydrocarbon gases, 0.4 per cent (by volume) - in oil mines of hazard group II for hydrocarbon gases; the composition of the mine atmosphere conforms to the requirements of paragraph 1731 of these Rules; the composition of the mine atmosphere is monitored by the AGK system.
1782. If the ventilation of the mine workings is disrupted, work in them is stopped, the power supply to the electrical equipment is switched off, and the workers leave these mine workings for mine workings with a mine atmosphere fit for breathing and report this to the mine dispatcher of the oil mine. If the VGP or VVU stops for more than 30 minutes, the workers go out to the surface and report this to the mine dispatcher of the oil mine. The decision to resume work after the restoration of the normal ventilation mode of the mine workings is taken by the technical manager of the oil mine.
1783. When monitoring the condition of the mine atmosphere of oil mines, the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons, the concentration of oxygen, carbon dioxide and other harmful gases, and the flow rate, temperature and relative humidity of the mine air are measured.
1784. The monitoring of the composition of the mine atmosphere is organised in accordance with Appendix No. 16 to these Rules. When monitoring the condition of the mine atmosphere, an assessment is made of the quality of the mine air and of the conformity of its actual distribution across the mine workings of the oil mine with the distributions determined by the design documentation, the mining operations documentation, and the oil production operations documentation.
1785. During an accident, the procedure for checking the composition of the mine atmosphere is established by the manager of the work on the localisation and elimination of the consequences of the accident.
1786. Measurements of the concentration of gases, and of the velocity, temperature and relative humidity of the mine air, are carried out with portable (of intermittent or continuous action) and stationary measuring instruments of an approved type that have passed verification.
1787. At the places where the air flow rate is measured, measuring stations are set up and notice boards are installed, on which are indicated the date of the measurement, the cross-sectional area of the mine working at the place of the measurement, the velocity of the air current, and the calculated and actual air flow rates.
1788. To monitor the composition of the mine atmosphere, the following are used: where the absolute gas content of mine workings is less than 3 m3/min - portable and (or) stationary devices for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours in mine workings where they have been detected, and portable devices for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours in mine workings where they have not been detected; where the absolute gas content of mine workings is 3 m3/min or more - stationary devices for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours in mine workings. Monitoring of the total content of hydrocarbon gases and liquid hydrocarbon vapours by stationary monitoring devices is carried out at heading machines, rock-loading machines, drilling rigs, and in operating pump chambers and hoisting machine and winch chambers. Where heading machines, rock-loading machines and pneumatically or hydraulically driven drilling rigs are remotely controlled, stationary devices for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours may be installed in the ventilation air current leaving the mine working, provided that the total content of hydrocarbon gases and liquid hydrocarbon vapours at the location of the remote control panel is monitored by portable devices for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours. In the mine workings of an oil mine, in accordance with the APK project, the arrangement of stationary technical devices for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours shall comply with the AGK project. The use of portable measuring devices in the AGK system is determined by the AGK project. Stationary technical devices for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours forming part of the AGK system shall ensure disconnection of electric power where the total maximum concentration of these gases and vapours is exceeded. The procedure for using portable and stationary automatic devices for monitoring the content of explosive gases is set out in Appendix No. 21 to these Rules. Monitoring of the total content of hydrocarbon gases and liquid hydrocarbon vapours is carried out using portable and stationary technical devices.
1789. When monitoring the mine atmosphere, measurements of the total concentrations of hydrocarbon gases and liquid hydrocarbon vapours are carried out in all mine workings where these gases and vapours may be released or accumulate. The locations and frequency of monitoring the total concentrations of hydrocarbon gases and liquid hydrocarbon vapours using portable technical devices are established by the head of the aerological safety service and approved by the technical manager of the oil mine. Where stationary technical devices are faulty, measurements of hydrocarbon gases and liquid hydrocarbon vapours are carried out using portable technical devices with the frequency established by the technical manager of the oil mine.
1790. Monitoring of the total content of hydrocarbon gases and liquid hydrocarbon vapours during blasting operations is carried out in accordance with the safety requirements for blasting operations.
1791. Before the work assignment is carried out, the employees issuing, approving and receiving the work assignment review the results of monitoring of the state of the mine atmosphere.
1792. At oil mines, a list of sections of mine workings hazardous due to layered accumulations of hydrocarbon gases and liquid hydrocarbon vapours is drawn up once a quarter.
1793. In dead-end workings and workings where debris clearance work is being carried out, monitoring of the carbon dioxide content by employees of the structural subdivisions carrying out work in these workings is performed at least once per shift. The measurement results are recorded on notice boards.
1794. Managers and employees of the oil mine, when visiting the mine workings of the oil mine, shall take measurements of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours and the concentration of carbon dioxide. Where the maximum concentrations of these gases and vapours are found to be exceeded, managers and employees of the oil mine shall act in accordance with the procedure set out in Appendix No. 17 to these Rules.
1795. At workplaces, the temperature, relative humidity and air velocity are measured every shift: at the beginning and end of mine workings where drilling and well operation work is carried out; in ventilation workings where work is carried out on injecting heat carrier into the formation and collecting the output of producing wells, along which hot pipelines are laid, during the period when work is being carried out in them - at the locations where the work is performed; in chambers; at workplaces where people are permanently present (machine operators, winch operators, operators and other employees); at the locations of employees servicing machines, mechanisms and control panels located outside chambers; in dead-end workings: at working faces during the loading of rock into transport vessels; at the mouths of dead-end workings.
1796. At the oil mine, a diagram of the main haulage roads is drawn up annually, showing: the lengths of haulage roads, passing sidings and their capacities, turnouts, and types of haulage along mine workings. The diagram of the main haulage roads is drawn up showing the haulage mode, including the procedure for performing shunting operations in the pit-bottom yard, the calculation of the number of mine cars in a train, the speed of train movement on individual sections of mine workings, and the main safety measures for the transportation of loads and people. The diagram of the main haulage roads is approved by the technical manager of the oil mine. All employees engaged in mining operations are familiarised with this diagram.
1797. Horizontal mine workings along which people and loads are transported by locomotives (hereinafter referred to as haulage) shall have a gradient of not more than 5‰. The gradient may be increased to up to 50‰ in cases where the mining and geological conditions do not allow the above requirement to be met. Sections of mine workings with laid rail tracks where passing takes place shall be horizontal.
1798. The curve radii of newly laid rail tracks and turnout curves for a 600 mm gauge shall be not less than 12 m. The curve radius of operating rail tracks with a 600 mm gauge in operating mine workings shall be not less than 8 m. At junctions of mine workings not intended for haulage, curves shall have radii of not less than 4 times the largest rigid wheelbase of the rolling stock.
1799. Operation of the rail track shall not be permitted where: vertical wear of the rail head exceeds 8 mm for R-18 rails, 12 mm for R-24 rails, 16 mm for R-33 rails and 20 mm for R-38 rails; the wheel flange of a mine car comes into contact with the heads of rail fastening bolts; there is damage to or defects in the rails that may cause the rolling stock to derail; the deviation of the rails from the track axis at joints (kink) exceeds 50 mm over a rail track length of less than 8 m.
1800. Turnouts in pit-bottom yards and main horizontal and inclined haulage workings are equipped with manual control or manual and remote control.
1801. Mechanical and manual drives of turnouts on haulage tracks are installed on the side of the pedestrian passage at a distance of not less than 0.7 m from the most protruding part of the drive to the edge of the rolling stock, and at a distance from the drive to the support that ensures ease of installation, inspection and repair. Turnout drives may be installed in niches.
1802. Operation of turnouts shall not be permitted where: switch blades are knocked out of alignment, chipped or bent in the longitudinal and transverse directions, or do not fit tightly against the stock rail and slide chairs; switch rods are disconnected; the switch is locked with a gap of more than 4 mm between the pressed point of the blade and the stock rail; there is no locking of the position of the turnout; turnout channels are open.
1803. Where haulage is carried out using mine cars equipped with safety catch devices, the use of metal packing plates shall not be permitted.
1804. In rope haulage along inclined mine workings, at curved approach sections of the rail track, guard rails are fastened to the running rails: on the inside - to the outer running rails, and on the outside - to the inner running rails. The outer guard rail shall project above the running rails by 40 mm.
1805. Rail tracks, track devices, drainage ditches, turnouts, track signals, clearances and passageways in horizontal and inclined haulage mine workings are inspected in accordance with the procedure established by the organisational and administrative document of the oil mine. Rail tracks are inspected by employees of the oil mine not less than twice a month. Verification of rail wear and levelling of the haulage road profile are carried out not less than once a year. The timing of levelling and the procedure for recording the levelling results are established by the technical manager of the oil mine.
1806. Where the distance to the workplace exceeds 1 km, specially equipped vehicles are used for the transportation of people.
1807. Passenger mine cars equipped with devices for signalling to the locomotive driver are used for the transportation of people. A single passenger mine car, positioned behind the locomotive at the head of the train, may be included in a freight train. Directly behind the passenger mine car, an empty mine car or one loaded within the rated carrying capacity is coupled. It shall not be permitted to couple a platform carrying materials or equipment, or mine cars in which the transported load protrudes beyond the clearance gauge, to the passenger mine car.
1808. Where haulage is carried out by battery locomotives, people may be transported in solid-body, non-tipping mine cars fitted with removable seats.
1809. A travel speed exceeding 20 km/h shall not be permitted when transporting people in passenger mine cars.
1810. The locomotive driver shall have a waybill indicating the condition of the locomotive and the locations of work being carried out along its route. When drivers change, the waybill is handed over with a note recording the handover and acceptance of the locomotive.
1811. Before dispatching a train carrying people, an inspection is carried out of the mine cars, coupling and signalling devices, wheelsets and brakes. Permission for the transportation of people is recorded in the waybill of the locomotive driver.
1812. When transporting people, the following shall not be permitted: the transportation in trains carrying people of tools and spare parts protruding beyond the side of the mine cars, or of explosive, flammable and caustic materials; the coupling of freight mine cars to passenger trains; the transportation of people on locomotives, in mine cars not equipped for the purpose, on platforms and decks. Not more than two freight mine cars may be coupled at the end of a passenger train for the transportation of tools. Explosive, flammable and caustic materials may be transported when accompanied by responsible persons.
1813. During movement, the locomotive is positioned at the head of the train. The locomotive may be positioned at the rear of the train when: performing shunting and marshalling operations over a section not exceeding 300 m in length; delivering trains of empty mine cars and platforms with materials to the face during the driving of single-track development workings over a distance not exceeding 400 m. When the locomotive is positioned at the rear of the train: the train speed shall not exceed 2 m/s; an empty mine car, or one loaded within the rated carrying capacity, is placed between the locomotive and the platform carrying materials; a light signal is fitted on the leading mine car or platform carrying materials, and while the train is moving, the electric locomotive driver shall periodically give audible signals.
1814. The transportation of people shall not be permitted during shunting operations and when delivering trains to the face.
1815. The delivery through mine workings of equipment and materials exceeding the clearance gauge of mine cars is carried out on special platforms fitted with devices for securing the loads being delivered.
1816. Mine cars, platforms, decks and tank cars (hereinafter referred to as transport vessels) shall have, on each end side, a buffer or automatic coupler ensuring a gap between the bodies of adjacent transport vessels of not less than 300 mm.
1817. A red light lamp is fitted on the last transport vessel of the train. When the locomotive is moving without transport vessels, a red light lamp is fitted on the rear of the locomotive. When the locomotive is positioned at the rear of the train, a white light lamp is fitted on the front outer wall of the leading transport vessel in the direction of travel.
1818. The braking distance of the train on the prevailing gradient shall not exceed 40 m when transporting loads, and 20 m when transporting people.
1819. Operation of locomotives shall not be permitted where: buffers are faulty; coupling devices are faulty; brakes are faulty or not adjusted; sanding boxes are faulty or contain no sand (except for locomotives with a coupled weight of up to 2 tf); headlights are not lit or are faulty; signalling devices are faulty; the explosion safety of equipment is impaired; brake shoes are worn by more than 2/3 of their thickness, or tyre wear exceeds 10 mm; the battery box cover is removed, or its interlocking device is faulty; electrical equipment, interlocking devices and protective devices are faulty.
1820. Storage batteries are charged in charging chambers equipped with charging devices. Charging and operating faulty or contaminated storage batteries shall not be permitted. Before a battery locomotive is dispatched onto the line, the hydrogen concentration in the battery box is measured. The maximum hydrogen concentration in the battery box shall not exceed 2.5 per cent.
1821. Repair of battery locomotives involving the opening of electrical equipment, other than the replacement of fuse links, is carried out in charging chambers or in mine workings equipped for this purpose.
1822. Garages for locomotive repair on the surface of the oil mine are equipped on dead-end rail tracks at distances of not less than 30 m from the shafts, and are fitted with permanently closed safety devices.
1823. The procedure and frequency for inspecting the condition of rolling stock are established by the organisational and administrative document of the technical manager of the oil mine.
1824. Transport vessels are inspected not less than once every six months. Inspection, cleaning and lubrication of transport vessels are carried out at a specially equipped station fitted with gauge frames for checking the dimensions of mine cars.
1825. Operation of transport vessels shall not be permitted: with faulty wheelsets; with faulty coupling devices; with faulty buffers and brakes; with faulty bottoms and hinges of locking mechanisms; with body walls that are damaged or bulged outward by more than 50 mm.
1826. During locomotive haulage, the following shall not be permitted: haulage of uncoupled trains; transportation of long loads without special transport vessels with a rigid coupling of a length ensuring the passage of the train on curves and vertical breaks of the rail track; manual coupling and uncoupling of transport vessels while the train is moving; pushing of trains by locomotives; coupling and uncoupling of transport vessels at a distance of less than 5 m from tipplers, ventilation doors or other obstructions; coupling and uncoupling of transport vessels in mine workings with a gradient exceeding 5‰; the use of a second locomotive as a pushing locomotive.
1827. During the operation of vehicles, the following shall not be permitted: leaving vehicles on rail tracks without being secured with stop blocks; leaving vehicles on rail tracks in workings with a gradient exceeding 5‰; leaving vehicles on curves and crossovers; stopping a moving vehicle by braking it with a device not intended for this purpose.
1828. During manual haulage, a lit lamp is hung on the front outer wall of the mine car or on the front part of the deck. The distance between transport vessels during manual haulage shall be not less than 10 m on tracks with a gradient of up to 5‰, and not less than 30 m on tracks with a greater gradient. Manual haulage shall not be permitted on tracks with a gradient exceeding 10‰, nor the simultaneous manual haulage of two or more coupled transport vessels.
1829. Pushers are used at the receiving platforms of bremsbergs and inclines, at the junctions of pit-bottom yards with the shafts, at the upper receiving platforms of headframe buildings, and near all tipplers. Control of the pushers is carried out from stations located in niches or other locations safe for operating personnel. The use of shunting winches at the receiving platforms of bremsbergs, inclines and shafts, and near all tipplers, shall not be permitted. Manual haulage of transport vessels is carried out in compliance with the safety measures approved by the technical manager of the oil mine.
1830. The persons responsible for organising the transportation of people and loads along inclined and vertical mine workings of the oil mine, and for the condition and inspection of ropes, hoisting machines, attachment devices and safety devices, are appointed by the organisational and administrative document of the oil mine.
1831. Acceptance into operation of the shaft guides after its construction or reconstruction, or after a new size type of hoisting vessel has been introduced, is carried out with the maximum load in the design operating modes over a period of 240 hours.
1832. The operating modes of hoisting plants for main and auxiliary operations are established by the organisational and administrative document of the oil mine.
1833. Cages used for lowering and raising people, and counterweight hoists intended for raising and lowering people and loads along inclined and vertical mine workings, shall meet the safety requirements applicable to mining operations.
1834. During the sinking, deepening and major overhaul of vertical and inclined shafts, people may be lowered and raised using temporary hoisting vessels without safety catch devices. After completion of shaft sinking work and the holing-through of shafts, cages or special mine cars fitted with safety catch devices are used for raising and lowering people in vertical and inclined mine workings.
1835. The lowering and raising of people in freight cages shall not be permitted, except in cases of shaft inspection and repair. The lowering and raising of people in loaded cages, and the transportation of loads on the roofs of cages used for lowering and raising people, shall not be permitted. Operation of the freight hoist during the lowering and raising of people shall not be permitted where a man-and-material hoist and a freight hoist are located in the same shaft.
1836. When operating man-riding and man-and-material hoisting plants: hoisting machines and winches intended for lowering people are fitted with an electric drive that operates in the electrodynamic braking mode during the deceleration period; the electric braking system, in the event of a fault in its circuit, shall act on the safety brake; winches used for lowering and raising people in cages and mine cars along inclined mine workings with an angle of inclination exceeding 18° and along vertical mine workings shall meet the requirements applicable to hoisting machines.
1837. The gap between the guide shoes of hoisting vessels and the guides shall not exceed: for rail guides - 5 mm per side; for timber guides - 10 mm per side. Shoes shall be replaced where the specified gaps increase: for rail guides weighing up to 55 kg/m - beyond 8 mm, and weighing 55 kg/m and above - beyond 12 mm; for timber guides - beyond 15 mm; for box-section guides - beyond half the wall thickness. The use of resilient guiding devices on hoisting vessels may be permitted only in combination with structurally separate rigid safety shoes installed directly on the load-bearing structure of the hoisting vessel. The initial gaps per side between the contact surfaces of the sliding safety shoes and the guides, at the time of their installation, are: for rail guides - 10 mm; for rectangular-section guides - 15 mm. Wear of the sliding guide shoes per side is permitted up to 8 mm, and the combined wear of the guide and shoe per side shall not exceed: for rail guides weighing up to 55 kg/m and box-section guides - 10 mm; for rail guides weighing 55 kg/m and above - 15 mm; for timber guides - 18 mm. Working or safety rigid sliding shoes newly installed during replacement shall, irrespective of the degree of wear of the guides, ensure the initial gaps.
1838. The throat depth of open-type sliding working shoes, at the time of their installation, shall be not less than: for rail guides weighing up to 45 kg/m - 60 mm; weighing 45 kg/m and above - 70 mm; for rectangular-section guides - 80 mm. The throat depth of sliding safety shoes, at the time of their installation, shall be not less than: for rail guides - 65 mm; for rectangular-section guides - 110 mm.
1839. The internal diameter of new bushes of guide sleeves for rope guides, at the time of their installation, shall be 10 mm greater than the diameter of the corresponding guide rope. Wear of the bushes of guide sleeves exceeding 15 mm in diameter shall not be permitted.
1840. Guides shall be replaced where wear reaches: for rail guides weighing up to 45 kg/m - more than 8 mm per side; for rail guides weighing 45 kg/m and above - more than 12 mm per side; for timber guides - more than 15 mm per side; for box-section guides - more than half the wall thickness; for rope guides - 15 per cent of the nominal rope diameter, but not more than half the height or diameter of the outer wires. Wear of the web connecting the head of rail guides to the base may be up to 25 per cent of its nominal thickness. Where cutting-type safety catches are used, timber guides shall be replaced where the combined wear of the side faces exceeds 20 mm. A full instrumental check of guide wear is carried out: for metal guides - annually; for timber guides - not less than once every 6 months.
1841. While the cage hoist is in operation, onsetters shall be present at the receiving (loading) platform of the headframe building, or, where the hoist is remotely controlled from a panel located at the receiving platform, the persons responsible for the boarding and disembarkation of people from the cage, and underground onsetters shall be present in the pit-bottom yards of operating levels. Where boarding and disembarkation of people from the cage takes place on both sides, onsetters and underground onsetters shall have assistants located on the other side of the cage. Boarding or disembarkation of people from the cage after the signal has been given shall not be permitted.
1842. People may be lowered and raised from intermediate levels without an onsetter present, subject to the following conditions: no receipt or dispatch of loads is carried out at the levels; the levels are equipped with working signalling to the hoisting machine operator and the underground onsetter, and direct telephone communication with them; an onsetter is present in the cage; the cage is equipped with telephone communication and signalling devices to the underground onsetter and the hoisting plant operator.
1843. At all levels of the oil mine, safety gates are installed in front of the shafts. During the raising and lowering of people, and also when the hoist is operating in the "inspection" mode, the load (mine car) exchange mechanisms at all receiving platforms of the shaft are disconnected. Where additional guards are provided preventing access of people to the shaft until the cage has come to a complete stop and during the period of its departure, guillotine-type doors may be used at the upper and lower receiving platforms.
1844. Notice boards are displayed at all boarding points and in the engine room, indicating: the surname and position of the person responsible for organising the raising and lowering of people; the schedule for raising and lowering people; the signals used; and the number of people simultaneously raised and lowered in each deck of the cage or in each passenger mine car.
1845. The automation system ensuring the operation of the hoisting plant without the permanent presence of personnel provides for: uninterrupted performance of the operations for raising and lowering the load and compliance with the specified speed diagram; automatic disconnection and safety braking of the hoisting machine where the established operating mode is violated; self-monitoring of the control system preventing a hazardous condition of the plant.
1846. The automation system provides for the possibility of implementing three modes of control of the hoisting plant: a mode ensuring operation of the plant for raising the load with automatic supply of the starting pulse from the loading device; a mode with the starting pulse supplied by the hoisting plant operator; a manual control mode for rope and shaft inspections and repair work. Switching from manual control to automatic or remote control may be carried out only after completion of the mine car exchange operation in the cage; switching to manual control mode is carried out irrespective of the position of the hoisting vessels.
1847. At the end of the automatic hoisting cycle, stopping of the machine is carried out by a signal supplied by a device monitoring the position of the vessel directly in the shaft.
1848. The control circuit of the automated hoisting plant provides for the main types of protection causing safety braking of the machines: protection against excessive wear of the brake shoes, activated where the gap between the drum rim and the brake shoe increases to more than 2 mm; protection against reverse running of the machine, activated before the speed of the vessel during reverse running reaches 1 m/s; protection against a twofold increase, compared with the design value, in the period of starting, deceleration or creeping; protection against impermissible heating of the bearings of the hoisting machine and the electric motor, including the stator; protection against damage to the electric circuit or the mechanical drive of the electric speed limiter; monitoring against earth faults in the control and protection circuits.
1849. On hoisting plants with a generator-motor drive system, in addition to the protections listed in paragraph 1848 of these Rules, the following are provided: maximum current protection of the hoisting motor and generator, zero-voltage protection of the mains motor of the converter unit, protection against a break in the excitation winding of the hoisting motor, and monitoring of earth faults in the main circuit of the generator and hoisting motor.
1850. The hoisting machine is equipped with control devices allowing the hoisting cycle to be completed, followed by a prohibition on starting a new cycle, in cases of an earth fault in the protection circuits and overheating of the compressor of the braking system.
1851. The control circuit of the automated hoisting plant provides an interlock meeting the following requirements: preventing the machine from being switched on in the direction of further overwinding, rope slackening or rope tensioning after an emergency stop; preventing the machine from being switched on where lubrication is absent; preventing switching from manual control to automatic control and back without the machine being braked by the safety brake; monitoring the normal loading and unloading of the hoisting vessels and preventing the machine from starting where these are disrupted. Speed limiters are duplicated; one of them may share a common drive with the programme control apparatus, while the other shall have an independent drive. This requirement does not apply to small hoisting machines with a hoisting speed of 4.5 m/s.
1852. During the operation of automated hoisting plants, the following are provided: at the mine dispatcher's station - light signalling of hoist operation and of the actuation of the safety brake, and a counter for the number of vessels raised; on the panel of the hoisting machine operator - a light signal for safety braking, for the condition of the loading device and for overfilling of the receiving hopper of the unloading device; a counter for the number of vessels raised; electrical measuring instruments in accordance with the control circuit; a fault locator in the protection circuit, or a device indicating which protection apparatus has actuated.
1853. For man-and-material hoisting plants, remote control of the hoisting machine may be used from the upper receiving platform. The remote control circuit provides for the possibility of manual control of the plant from the hoist house and of remote control from the upper receiving platform. Setting of the "load-people" operating mode is carried out by means of a switch on the remote control panel of the hoisting machine. The plant operating mode switch is interlocked with the switch of the "load-people" signalling system in such a way that the protective devices prevent the vessel from being raised above the level of the platforms for disembarking people. During remote control of the man-and-material hoist, an interlock is provided precluding the possibility of simultaneous control of the hoisting machine from the remote control panel and from the hoist house.
1854. In oil mines with a depth exceeding 100 m, one of the flank (side) ventilation shafts used as an emergency exit is equipped with a hoisting plant for carrying out shaft inspection and repair work and for lowering and raising people in the event of accidents, breakdowns of the hoisting machine, or cages becoming stuck in the shaft (hereinafter referred to as emergency repair hoisting plants).
1855. Emergency repair hoisting plants are equipped with: ropes of a length corresponding to the depth of the shaft and a safety factor of not less than 9 times the maximum design static load; hoisting vessels with a capacity of not less than two persons; guide sheaves and signalling equipment enabling signals to be given from the hoisting vessel and from the levels from which people are expected to be taken out. For equipping emergency repair hoisting plants at oil mines, winches fitted with working and safety braking devices may be used. People may be lowered and raised in the hoisting vessels of emergency repair plants without safety catch devices, and ropes may be wound in multiple layers onto the drum of the hoisting machine, provided that the drum flange projects above the top layer of rope winding by not less than 2.5 times its diameter.
1856. Auxiliary hoisting installations are equipped with: ropes of a length corresponding to the depth of the shaft and with a safety factor of not less than 9-fold in relation to the maximum design static load; conveyances with a capacity of not less than six persons; signalling that allows signals to be given from the conveyance and from the levels from which people are to be conveyed out. The speed of movement of the conveyances shall be 2 m/s at a hoisting height of up to 600 m, and 3 m/s at a hoisting height of more than 600 m. The lowering and raising of people in the conveyances of auxiliary hoisting installations without safety catch devices and multi-layer winding of ropes onto the drum of the hoisting machine are permitted.
1857. Inspection and checking of emergency-repair and auxiliary hoisting installations are carried out not less than once a week by an employee of the oil mine and not less than once a month by the chief mechanic of the oil mine.
1858. The lowering and raising of people is permitted after a preliminary check by the hoisting machine operator of its serviceability and a no-load run of the cages.
1859. The main hoisting installation is provided in reserve with: a tested rope that has undergone instrumental inspection; a conveyance with attachment gear; an electric motor or a full set of spare parts for it; a compressor with an electric motor where there is no supply from the mine-wide pneumatic system; a set of brake shoes; the necessary quantity of spare bearing shells or rolling bearings, high-speed shafts and rapidly wearing elements of the monitoring, control and protection apparatus, as determined by the manufacturer's operating documentation.
1860. At the hoisting installation, the availability of the following is ensured: a schedule of hoist operation, approved by the technical manager of the oil mine, indicating the time required for carrying out daily inspections of the elements of the hoisting installation; the data sheet of the hoisting machine and reduction gear; a detailed diagram of the braking device indicating the main dimensions; as-built electrical diagrams; a diagram of the safety catch devices with the controlled dimensions; instructions for the hoisting machine operator; a hoisting installation inspection log, a log of rope inspection and rope consumption, a log of shift handover and acceptance by hoisting machine operators, the form and procedure for keeping of which are established by an organisational and administrative document of the oil mine. The diagram of the braking device, the as-built electrical diagram, the diagram of the safety catch devices and the instructions for the hoisting machine operator are displayed in the machine room.
1861. The hoisting installation and its elements are inspected and checked in accordance with a schedule developed by the chief mechanic of the oil mine and approved by the technical manager of the oil mine: every shift by the hoisting machine operator, the onsetter, the underground onsetter and the duty fitter; every day by a specialised work team under the direction of an employee of the oil mine; every month by the chief mechanic of the oil mine. The safety brakes and protective devices of the hoisting installation are checked not less than once every 15 days by the chief mechanic of the oil mine. The results of inspections and checks are entered in the shift handover and acceptance log and the hoisting installation inspection log.
1862. Inspections of metal headframes are carried out not less than once a year by a commission the composition of which is determined by an organisational and administrative document of the oil mine. The results of the inspection are documented in a report approved by the technical manager of the oil mine. Not less than once a year, a check of the geometric alignment of the shaft hoist and the headframe is carried out. The results of the check are documented in a report which is approved by the technical manager of the oil mine.
1863. Examination and adjustment of the hoisting installation is carried out before it is put into operation and not less than once a year during operation. The electrical part and equipment of automated hoisting installations shall be subject to examination and adjustment not less than once every 6 months. After examination and adjustment of the hoisting installation, its control tests are carried out, on the basis of the results of which a report is drawn up, approved by the chief mechanic of the oil mine. Not less than once every 6 months after examination and adjustment, each hoisting installation is subjected to a technical inspection and test, on the basis of the results of which a report is drawn up, approved by the chief mechanic of the oil mine.
1864. The repair and inspection of the shaft may be carried out from the roof of an unloaded cage or from an inspection platform equipped on the skip or counterweight, subject to compliance with measures ensuring the safe performance of the work: coverings protecting workers from falling objects are provided above the roof of the cage or above the inspection platform; the area of the inspection platform shall be not less than 0.6 m, with one of the linear dimensions being not less than 0.4 m, and the height of the platform guard rail shall be not less than 1.2 m; workers located on the roof of the cage or the inspection platform are attached to the hoisting rope by means of a fall arrest system. During the repair (inspection) of the shaft, only persons engaged in this work may be present on and inside the conveyance. For the inspection and repair of sections of the shaft support and shaft equipment remote from the conveyances, folding stages (removable), securely attached to the conveyance, may be used. On hoisting installations with counterweights, the inspection and repair of the shaft is carried out using a balancing load in the conveyance. During the inspection of the shaft, the speed of movement of the conveyance shall be not more than 0.3 m/s.
1865. The deflection angle (fleet angle of the rope span), the length of the rope span and its angle of inclination to the horizontal for hoisting installations shall comply with the requirements of the safety rules for the conduct of mining operations.
1866. Sheaves with cast or stamped rims for which the use of lining is not provided for are replaced with new ones when the rim or flange is worn by 50 per cent of its initial thickness and in all cases where the ends of the spokes become exposed. Build-up welding of the sheave groove is permitted where it is worn to a depth of not more than 50 per cent of the initial thickness, with subsequent quality control of the work performed by a non-destructive testing method. Before the installation of a new rope and thereafter not less than once a quarter, an inspection of the sheaves is carried out by the chief mechanic of the oil mine or a person authorised by him. The results of the inspection are entered in the hoisting installation inspection log.
1867. The segments of the lining of the headframe sheaves are secured in such a way that there are no connecting parts on the edges of the lining groove which, if their fastening fails, could fall into the groove under the rope. The condition of the lining fastening is checked weekly. The lining segments are replaced with new ones when they are worn in depth by one rope diameter (excluding the initial recess) and to the side by 0.5 of the rope diameter, and also where the residual height of the lining, as a result of wear, becomes equal to 0.75 of the rope diameter.
1868. The length of the overwind for single-rope hoisting installations of vertical and inclined workings (with an angle of inclination of more than 30°) shall be not less than: 6 m for hoisting installations with a hoisting speed of more than 3 m/s; 4 m for hoisting installations with a hoisting speed of up to 3 m/s.
1869. To protect against overwind and overspeed, the mine hoisting installation is provided with safety devices.
1870. The top and bottom landings of cage shafts are equipped with landing dogs or swinging platforms. At intermediate levels, swinging platforms are used. The use of landing dogs at intermediate levels is permitted with the authorisation of the technical manager of the oil mine. It is permitted not to equip the top and bottom landings with landing dogs or swinging platforms on hoists not used for the transport of loads, provided that accurate stopping of the conveyance at the landings is ensured and the clearance between the cage and the shaft support at the level of the passage of people does not exceed 150 mm.
1871. At the boarding platforms of intermediate levels and the boarding platforms of lower levels equipped with landing dogs, signalling and interlocking devices are installed. Information about the position of the dogs or swinging platforms from these levels is transmitted to the hoisting machine operator. The interlocking devices of the landing dogs prevent their extension and ensure their return to the inoperative (fully retracted) position when the speed of movement of the hoisting machine exceeds 1 m/s. The interlocking devices of the swinging platforms prevent their engagement and ensure their return to the inoperative (raised) position when there is no cage at the level of the landing.
1872. Shafts through which the lowering and raising of people is carried out shall have sumps. The free depth of the sump for single-rope hoisting installations shall be not less than the overwind height. The absence of a sump and the presence of landing beams are permitted for shafts through which only the transport of loads is carried out, and also for shafts intended for the raising of people in an emergency.
1873. The loading of transport vessels into the cage is carried out by pushers or using the gradient of the rail track. The stops, pushers, track brakes and safety gates are interlocked with the cage in such a way that they can be engaged only after the cage has been set on the landing devices.
1874. The maximum speed of raising and lowering of people and loads along vertical and inclined mine workings shall not exceed the values given in Appendix No. 22 to these Rules.
1875. The design value of the acceleration of hoisting installations intended for the raising and lowering of people shall not exceed: 1 m/s2 for vertical and inclined (more than 30°) installations; 0.7 m/s2 for inclined installations up to 30°. The magnitude of the acceleration for load hoisting installations is determined by the design documentation. The design value of the deceleration of hoisting installations shall not exceed: 0.75 m/s2 for vertical and inclined (more than 30°) installations; 0.5 m/s2 for inclined installations up to 30°.
1876. The magnitude of the average deceleration of the hoisting installation during lowering under safety braking shall be not less than 0.75 m/s2 at angles of inclination of mine workings up to 30° and not less than 1.5 m/s2 at angles of more than 30°. The magnitude of the average deceleration of the hoisting installation when raising the design load shall not exceed the values given in Appendix No. 23 to these Rules. The deceleration values for intermediate angles of inclination of mine workings not specified in Appendix No. 23 to these Rules are determined by linear interpolation.
1877. The simultaneous operation, in one mine working, of technical devices for the lowering and raising of people and means of rail transport for the lowering and raising of loads shall not be permitted, except in cases of repair of these mine workings. The use of a single technical installation for the lowering and raising of people and loads is permitted only where the changing (re-coupling) of conveyances is not carried out in doing so. For the transport of people, cages, passenger cars, suspended cableways and monorail roads equipped with passenger or goods-and-passenger cars are used. For the delivery of materials and the removal of rock during repairs of men's travelling ways equipped with mechanical delivery, a load car may be coupled to an unloaded passenger train. In this case: the speed of the train shall not exceed 3 m/s; attachment devices intended for these purposes are used for coupling the load car; the load on the attachment device of the leading passenger car and on the winch shall not exceed the design load. The transport of people in a passenger train with a coupled load car shall not be permitted.
1878. The overwind distance for hoisting installations in inclined mine workings with an angle of inclination up to 30° shall be not less than: 6 m on double-ended hoisting installations; 2.5 m on operating single-ended load hoisting installations and not less than 4 m on those being designed; 4 m on single-ended goods-and-personnel and personnel hoisting installations.
1879. Where drifts intersect with inclined mine workings used for the transport of loads and people, barriers with a remote opening system and illuminated warning indicators are installed in the drifts.
1880. The transport of people along inclined mine workings equipped with end-rope haulage is carried out by passenger cars. In workings with small angles of inclination with a variable profile (5° - 10°), the transport of people using winches with two ropes is permitted. When transporting people along inclined mine workings with rail transport, technical devices are used that ensure a smooth stopping of the train (car) when the set speed is exceeded by 25 per cent, or when the rope, attachment device or coupling breaks, with the possibility of checking its operability from a manual drive. The types of the safety catch device and the running gear of the cars used shall correspond to the types of rails and the methods of laying the rail tracks. On cars used for the transport of people along double-track mine workings, and also along mine workings in which the boarding platforms are located on one side, the openings on the non-working side and the spaces between the tracks are closed off completely.
1881. A red light signal is installed on the first transport vessel in the direction of movement of the train along the inclined mine working.
1882. The raising and movement of people along inclined mine workings during the raising and lowering of loads along them shall not be permitted.
1883. During the lowering or raising of people and loads in inclined mine workings, the entry onto the platforms on which the coupling and uncoupling of transport vessels is carried out, by persons not participating in this work, shall not be permitted. During the lowering and raising of a load, being within the operating zone of the haulage rope on the top platform and, on the bottom platform, outside the recess for sheltering workers, shall not be permitted. Warning signs are posted on the approaches to the platforms and on the platforms themselves.
1884. With end-rope haulage along inclined mine workings, retaining stops are used on the top landings with horizontal accesses; below the top and above the bottom landings with horizontal accesses, and at the accesses of all landings with inclined accesses, buffer barriers with automatic or remote control are installed. Where the installation of a buffer barrier is not possible, the train of cars, when moving up and down, is provided with a safety rope against the uncoupling of the cars, and, when moving up, with a removable catcher installed on the last car relative to the rope capel. With endless-rope haulage, on the tracks of the loaded and empty branches of an inclined shaft, dip or brake incline, catchers are installed in the following order: below the top and intermediate landings, above the bottom and intermediate landings - two catchers: the first at a distance of 5 m from the landing, the second at a distance of 5 m from the first.
1885. The stops and barriers shall be permanently closed and are opened only to allow the passage of cars. At intermediate and bottom landings, recesses for sheltering people are provided. On district inclined mine workings less than 30 m in length intended for the delivery of loads, the use of manually operated barriers is permitted. The requirements of this paragraph do not apply to inclined mine workings used only for the transport of people.
1886. With load haulage by endless and end ropes, coupling and attachment devices that prevent spontaneous uncoupling are used, and with endless-rope haulage in workings with an angle of inclination of more than 18°, additionally, counter-chains. The coupling devices of the cars and the attachment devices for endless-rope haulage shall have a safety factor of not less than 6-fold, and the attachment devices for end-rope haulage shall have a safety factor of not less than 10-fold in relation to the maximum design static load. Attachment devices of the "baranchik" type for endless-rope haulage shall have a 4-fold safety factor in relation to the yield strength of the material. Attachment devices of the "baranchik" type are tested with a load 2.5 times greater than the design static load. The repair of attachment devices of the "baranchik" type shall not be permitted.
1887. Attachment devices for end-rope and endless-rope haulage are marked, indicating the permissible load, the number and the year of manufacture. With end-rope haulage, the attachment devices are tested after each capping of the rope by lowering and raising a load of the maximum permissible mass. The results of the tests are entered in the hoisting installation inspection log.
1888. The lowering and raising of loads along inclined mine workings equipped with hoisting installations shall not be permitted where there are no workers to service the receiving and dispatching operations at the levels to which the delivery of loads is carried out.
1889. Locomotive haulage at the landings of inclined mine workings shall not be permitted where the haulage rope of a winch installed in an inclined mine working is located in the cross-section of the working along which locomotive haulage is being conducted.
1890. The operational clearances between the maximally protruding parts of the hoisting devices of stationary hoisting installations, the support and the buntons in vertical shafts are given in Appendix No. 24 to these Rules. The clearance between moving buckets and the shaft support or the protruding parts of equipment located in the shaft shall be not less than 400 mm. The clearance between the walls of the bell-mouth of the sinking stage and the protruding parts of the moving guide frame of the bucket shall be not less than 100 mm. Before starting a newly installed or repaired hoisting device or counterweight, after repair work in the shaft involving the alignment of the shaft equipment, guides or support, and after objects that may affect the position of the shaft equipment have fallen into the shaft, a check of the clearances is carried out. After repair involving the replacement of the shaft equipment or guides, a profiling of the guides is carried out.
1891. In mine shafts, ropes with a flame-retardant sheath are used.
1892. For personnel and goods-and-personnel hoisting installations, hoisting and haulage goods-and-personnel ropes of grades VK and V are used, and the rest - not lower than grade 1 (hereinafter referred to as ropes).
1893. The use of single-lay ropes made of round wires for the suspension of sinking equipment, and of locked-coil hoisting ropes as guides for bucket hoisting, shall not be permitted.
1894. On single-rope hoisting installations with rope guides, head ropes of the same diameter, construction and lay direction are installed for both conveyances.
1895. With endless-rope haulage along inclined workings, single-layer round-strand ropes of cross lay are used.
1896. The ropes of mine winches shall have, at installation, a safety factor in relation to the maximum design static load of not less than: 7.5-fold for the suspension of grabs and sinking cradles in the shaft; 6.0-fold for sinking units and units for equipping the shaft; 4.0-fold for scraper, shunting and haulage winches along horizontal mine workings.
1897. Haulage ropes for moving face equipment shall have a safety factor of not less than 3-fold in relation to the nominal force on their working drums.
1898. As bottom balance ropes on hoists, flat ropes, non-spinning round single-layer stranded ropes of cross lay and multi-strand ropes are used. When round stranded ropes are used as balance ropes, their attachment to the conveyances at both ends is effected through swivel attachment devices.
1899. As balance ropes for load single-rope hoisting installations, it is permitted to use rubber-cable ropes in a fire-resistant design with a number of reinforcing cables of not less than 12. The jointing of rubber-cable ropes is carried out in accordance with the manufacturer's technical documentation for their jointing.
1900. The head ropes of personnel and goods-and-personnel hoisting installations, the haulage ropes of monorail roads and the haulage-carrying ropes of passenger cableways shall be of grade V. The head ropes of load hoisting installations, the bottom balance ropes, haulage ropes, guide ropes, brake ropes and ropes for the suspension of equipment shall be not lower than grade 1. A rope is rejected if, during the testing of its wires before installation, the total cross-sectional area of the wires that failed the bending and tensile tests is: 6 per cent for grade V ropes serving for the raising and lowering of people; 10 per cent for load ropes.
1901. As rope guides and rubbing ropes, locked-coil construction ropes having shaped-profile wires of a height of not less than 5 mm in the outer layer are used. For these purposes, round-strand non-spinning single-layer ropes of cross lay with a metal core and an outer wire diameter of not less than 2 mm, and galvanised ropes of the ZhS group, are used.
1902. As cushioning and brake ropes of safety catches, non-spinning round-strand ropes of cross lay with an organic core are used. The diameter of the outer wires of the brake ropes shall be not less than 2 mm.
1903. For scraper, shunting and haulage winches, single-layer stranded ropes with an organic or metal core are used.
1904. Between the branches of the bottom balance rope in the sump part of a vertical mine working of the oil mine, devices are installed that prevent twisting of the rope and eliminate the possibility of the bottom rope breaking during overwind. The loop of the bottom balance rope shall be greater than the possible overwind height of the upper conveyance. The flooding with water of the loops and tensioning devices of the bottom balance rope and the brake ropes shall not be permitted.
1905. The hoisting ropes of vertical and inclined mine hoists, with the exception of ropes on load inclined hoists with an angle of inclination of less than 30°, the haulage ropes for monorail roads, and the haulage and carrying ropes for underground cableways, are tested at rope-testing stations before their installation.
1906. It is permitted not to test, before installation, the brake ropes of safety catches, the bottom balance, guide and rubbing ropes, and the ropes for the suspension of equipment in vertical mine workings, and to determine their safety factors according to the manufacturer's operating documentation.
1907. Ropes, with the exception of ropes in installations with friction sheaves and ropes of underground passenger suspended roads, are re-tested: not less than once every 6 months on personnel and goods-and-personnel hoisting installations; not less than once every 12 months after installation and thereafter not less than once every 6 months on load, emergency-repair and mobile hoisting installations; not less than once every 6 months after installation, and thereafter not less than once every 3 months, hoisting multi-strand non-galvanised low-rotation ropes (load and goods-and-personnel); not less than once every 18 months after installation, and thereafter not less than once every 6 months, the ropes of vertical hoists and inclined personnel and goods-and-personnel hoists (with an angle of inclination of more than 60°) that are checked with rope flaw detectors. The period for re-testing of ropes is counted from the moment of their installation.
1908. The haulage and tensioning ropes of underground passenger cableways and the haulage ropes of monorail and floor-mounted roads are tested before installation. The haulage ropes of monorail and floor-mounted roads are re-tested not less than once every 6 months.
1909. A rope is replaced by another if, during re-testing, the total area of the wires that failed the tensile and bending tests reaches 25 per cent of the total cross-sectional area of all the wires of the rope.
1910. A length of rope sent for testing shall be not less than 1.5 m long. For re-testing, the length of rope located above the last clamp of the capel or the adjustable wedge thimble is sent.
1911. A length of rope is inspected before testing, and data on all detected defects are entered in the rope test certificate. The rope test certificates are kept at the oil mine throughout the entire service life of the rope.
1912. Devices for joining ropes are inspected not less than once a week. Where thimble splices with clamps are used, the reliability of the connection is checked not less than once every 3 months by tightening the nuts.
1913. The ropes of mine hoisting installations are inspected: every day - the hoisting ropes of conveyances and counterweights of vertical and inclined hoisting installations, the balance ropes of hoisting installations with friction sheaves, the ropes for the suspension of mechanical loaders (grabs) during shaft sinking; every week - the balance ropes of hoisting installations with drum-type machines, the brake ropes of safety catches and the guide ropes, the ropes for the suspension of stages, cable and sinking equipment, and also the hoisting and balance rubber-cable ropes, and the ropes of scraper, shunting and haulage (along horizontal workings) winches, with the participation of an employee of the oil mine; every month - the cushioning, hoisting and balance ropes, including the rope attachment sections, with the participation of the chief mechanic of the oil mine; the ropes permanently located in the shafts, with the participation of an employee of the oil mine; once every two weeks - the rubbing ropes.
1914. All ropes are inspected along their entire length at a speed of movement of not more than 0.3 m/s. Damaged sections of ropes, and also the butt joints of rubber-cable ropes, are inspected with the rope stationary. On hoisting installations, the daily inspection of ropes in which the number of broken wires does not exceed 2 per cent of the total number of wires of the rope over the length of one lay is carried out at a speed of movement of not more than 1 m/s.
1915. It shall not be permitted to install and use steel ropes with broken, protruding or sunken strands, with knots, "zhuchki" and other damage, and also with a reduction in the nominal diameter of more than 10 per cent.
1916. The use of spliced ropes is permitted only for endless-rope haulage of loads along horizontal and inclined mine workings with an angle of inclination up to 30°, and on underground passenger suspended cableways, monorail and floor-mounted roads. During shaft sinking, where ropes more than 1000 m long are used for suspended equipment, their connection by paired thimbles with the installation of clamps on each branch of the rope is permitted.
1917. The operation of steel stranded ropes of mine hoisting installations shall not be permitted where, on any section, there are wire breaks the number of which, over one lay length, out of the total number in the rope, reaches: 10 per cent for the balance, brake, cushioning, guide and rubbing ropes of load inclined hoists with an angle of inclination up to 30°; 5 per cent for the hoisting ropes of other hoists, and the ropes for the suspension of stages and mechanical loaders (grabs). In the log of rope inspection and rope consumption, the most damaged section (lay) on which the number of broken wires exceeds 2 per cent of the total number of wires of the rope is noted. The protruding ends of broken wires are removed.
1918. The operation of locked-coil construction hoisting ropes shall not be permitted where there is: wear of the wires of the outer layer by more than half of their height; disruption of the lock of the shaped-profile outer wires (delamination of the wires); a wire coming out of the lock onto the surface of the rope, if it cannot be fixed back into the rope or soldered; the presence of 3 broken wires, including soldered ones, of the shaped profile of the outer layer over a section length equal to 5 of their lay lengths, or 12 over the entire working length of the rope. The operation of ropes having wave-like sections without disruption of the lock of the outer wires and retaining a smooth surface is permitted until there is clear disruption of the lock (delamination) of the outer wires or a single wire comes out of the lock on the said section. It is permitted, where a single outer (Z-shaped) wire comes out of the lock on a straight rope (both in the absence and in the presence of a break), to unbraid it along the entire length of the rope and to continue its operation, if the gap that has appeared in the layer of outer wires does not lead to disruption of the lock between them.
1919. Guide ropes shall be subject to replacement: when the outer wires are worn by more than 50 per cent of their height; if, over 100 m of the length of a locked-coil construction rope, two breaks of outer wires are found. If, upon breaking, the outer wires of a locked-coil construction rope come out of the lock, they are soldered.
1920. Upon expiry of the maximum service lives, ropes are replaced, or their service life is extended, on the basis of the results of flaw detection, analysis of the dynamics of the hoisting installation's operation and determination of the residual durability of the rope.
1921. The ropes of auxiliary transport shall be subject to inspection in the manner established by an organisational and administrative document of the oil mine: every day - the ropes of passenger suspended cableways and goods-and-personnel monorail and floor-mounted roads, and the ropes of auxiliary winches in inclined mine workings; every week - the ropes of passenger suspended cableways, endless haulages, monorail and floor-mounted roads, and the ropes of scraper, shunting and auxiliary winches; not less than once every six months - the ropes of passenger suspended roads, monorail and floor-mounted roads. The ropes of roads and winches in horizontal and inclined mine workings are inspected along their entire length at a speed of movement of not more than 0.3 m/s. The inspection of ropes on operating roads having a speed of less than 0.3 m/s, and of the ropes of winches with a non-adjustable speed, is carried out with the hoisting installation stopped.
1922. The operation of steel stranded ropes of auxiliary transport shall not be permitted where, on any section, there are wire breaks the number of which, over one lay length, out of the total number in the rope, reaches: 5 per cent for the ropes of underground passenger suspended cableways, monorail and floor-mounted roads; 15 per cent for the ropes of load winches in inclined mine workings; 25 per cent for the ropes of endless haulages along inclined mine workings, and the ropes of scraper, shunting and auxiliary (along horizontal mine workings) winches.
1923. Ropes for moving face equipment are checked: every shift before the start of work - by the hoisting machine operator or his assistant; every week - by an employee of the oil mine. Ropes are replaced if, over one lay length, the number of wire breaks reaches 10 per cent of the total number of wires in the rope.
1924. If, during operation, the ropes of a hoisting installation have been subjected to loads exceeding the maximum permissible loads, its operation is stopped and the ropes are inspected.
1925. Stranded hoisting ropes used in vertical shafts, and on man-riding and man-and-material hoists in inclined mine workings, suspended with a safety factor relative to the maximum design static load of less than 6-fold, are subjected to instrumental testing to determine the loss of steel cross-section of the ropes along their entire length.
1926. Ropes are removed and replaced with new ones when the loss of steel cross-section of the ropes reaches: 10 per cent - for hoisting ropes in vertical shafts with a plumb length of more than 900 m, for hoisting ropes of man-riding and man-and-material hoisting installations not equipped with catch gear, and for the brake ropes of catch gear; 15 per cent - for hoisting ropes with a metal core, triangular-strand ropes, ropes with round plastically compacted strands, and for ropes of all constructions in vertical shafts with a plumb length of up to 900 m; 18 per cent - for round-strand ropes with an organic core on man-riding, man-and-material and material hoists with a diameter of 45 mm or less, and for guide ropes; 20 per cent - for round-strand ropes with a diameter of more than 45 mm with an organic core on vertical material hoists with a safety factor relative to the maximum design static load of not less than 6.5-fold; 24 per cent - for balance ropes.
1927. Platforms are provided for the inspection of hoisting ropes and lower balance ropes, allowing the ropes to be inspected along their entire length.
1928. When instrumental testing of rubber-cable ropes is carried out, the integrity of the cables is determined.
1929. Cages for man-riding and man-and-material hoisting are equipped with a double independent suspension - a working suspension and a safety suspension. Counterweights of single-rope hoists need not be equipped with a safety suspension.
1930. The safety factor of suspension devices at the point of attachment, relative to the maximum static load, shall be not less than: 13-fold - for suspension devices of man-riding, man-and-material and auxiliary hoists; 10-fold - for suspension devices of material hoisting, and suspension devices of pipelines and equipment; 6-fold - for suspension devices of guide ropes and buffer ropes.
1931. The type of a suspension device shall ensure that the rope attachment strength is not less than 85 per cent of the rope's aggregate strength. On operating hoisting and transport installations, the service life of suspension devices shall not exceed 5 years from the date of attachment. Where a suspension device is reused, its total period of operation shall not exceed 5 years.
1932. Suspension devices of balance ropes shall have a 6-fold safety factor relative to the maximum static load of the head rope(s).
1933. Suspension devices in inclined or vertical mine workings under construction: are tested for double end load before attachment and at least once every 6 months during operation; are replaced with new ones at least once every 2 years; are equipped with devices that reliably close the hook throat while the hoisting vessel is moving, preventing its spontaneous release.
1934. The use of chains manufactured by forge welding or manual electric welding as safety suspensions shall not be permitted.
1935. The ratio of the smallest rope winding diameter on the drum of a hoisting machine or winch to the rope diameter shall be not less than: 120 - for single-rope hoisting machines with a friction sheave; 79 - for guide sheaves and drums of surface single-rope hoisting installations; 60 - for guide sheaves and drums of underground hoisting machines and winches, and hoisting machines of auxiliary hoisting installations; 50 - for mobile hoisting machines, guide sheaves and drums of winches for waste-rock dumps and haulage winches, for machines and winches of emergency-repair hoisting installations, for drive and tensioning sheaves of underground passenger and suspended cableways, and for drive sheaves of monorail roads; 35 - for end sheaves of monorail roads; 25 - for sheaves of the tensioning device of monorail roads, and for deflecting sheaves of guide ropes where their tension is provided by weights located on the headframe; 6 - for support and pressure rollers of underground passenger suspended cableways with a roller diameter of not less than 100 mm.
1936. On vertical and inclined surface hoists, as well as underground man-and-material and man-riding hoists with an inclination angle of more than 60°, single-layer winding of ropes onto drums is used. On hoisting machines of vertical material hoists installed on the surface, double-layer winding of ropes onto drums may be used. Triple-layer winding may be used on all other hoists, as well as when sinking vertical and inclined mine workings. Drum lining shall have cut grooves irrespective of the number of layers of rope winding. Where more than one layer of rope is wound onto a drum, the drum flange shall project above the top layer by 2.5 rope diameters. On mobile and auxiliary material hoisting installations, and on sinking material winches with a speed of not more than 0.2 m/s, multi-layer winding may be used with a flange height above the top layer of winding of not less than 1.5 rope diameters. On sinking winches with a speed of not more than 0.2 m/s, drums without lining and cut grooves may be used.
1937. On drums lined with friction material, there shall be not less than 3 turns of friction; on drums not lined with friction material - not less than 5 turns of friction.
1938. Hoisting machines and winches are equipped with a working brake and a safety brake with independent drive engagement. On winches intended for lowering and raising equipment and materials along inclined workings, 2 brakes are installed. This requirement does not apply to auxiliary material winches with a load capacity of up to 200 kg and a rope capacity of up to 100 m.
1939. Safety braking of a hoisting machine is effected by a weight or springs. The number of springs shall be such that, if one of them fails, the braking force generated by the drive is reduced by not more than 15 per cent. For man-and-material hoisting installations, brake devices with spring drives shall have two drives. Safety braking of a hoisting machine is effected both by the operator and automatically. Engagement of the safety brake is accompanied by disconnection of the hoisting motor from the mains.
1940. A hoisting machine is fitted with a locking device ensuring adjustment of the drum position and repair of the brake device. Where drums allowing remote disconnection from the shaft are used, an interlock is provided ensuring pre-locking of the drum being released or its movable part.
1941. When the machine or winch is in the braked state, the torque developed by the safety brake shall be not less than 3 times the static load torque. On an operating machine or winch, the working brake shall provide a braking torque of not less than 3 times the static load torque. The minimum ratios of the torques developed by the safety brake in the braked state of the machine to the static torques are given in Appendix No. 25 to these Rules. For inclined mine workings with variable angles of inclination, the braking torque is taken based on the largest angle of inclination of the working. When repositioning an idle drum, the brake device shall generate, on one brake pulley, a braking torque of not less than 1.2 times the static torque created by the weight of the hoisting vessel and one branch of the rope.
1942. After replacement of elements of the brake system, the system is tested.
1943. The brake actuator is fitted with interlocks preventing the machine from being released from braking in the event of excessive wear of the brake shoes. This requirement does not apply to winches and hoisting machines with a weight-driven brake, on which the working brake is released manually.
1944. The idle running time of the safety brake of hoisting machines shall not exceed: 0.5 s - with a pneumatic-weight brake drive; 0.6 s - with a hydraulic-weight brake drive; 0.3 s - with pneumatic-spring and hydraulic-spring brake drives. For sinking winches, the idle running time shall not exceed 1.5 s. The response time of the safety brake, including the idle running time, irrespective of the type of brake drive, shall not exceed 0.8 s.
1945. Hoisting machines and winches are fitted with a depth indicator showing the hoisting machine operator the position of the vessels in the shaft, and an automatic bell signalling the need to begin the deceleration period.
1946. A hoisting machine shall have: a voltmeter and an ammeter; pressure gauges showing the pressure of compressed air or oil in the brake system; a recording speedometer for machines with a speed exceeding 3 m/s installed on the surface.
1947. Drilling of wells from the surface, and of underground wells of all purposes (production, injection, ventilation, process, and for laying cables and pipelines) (hereinafter - wells) in underground oil mining, is carried out in accordance with the design documentation, the documentation for conducting oil production work, and the TR.
1948. When drilling a well from the surface, as its bottom approaches a mine working at a distance established by the design documentation, in the section of the mine working where the well may intersect the mine working, the following shall not be permitted: carrying out work; movement of people and vehicles; pumping of liquids through pipelines; transmission of electric power through cables laid in that section.
1949. Warning signs are posted at the boundaries of the area where the well intersects the mine working.
1950. A work order is issued for the construction, operation and repair of underground wells.
1951. In mine workings where underground wells will be constructed, operated and repaired, board flooring for the passage of personnel is laid, the thickness and slope of which are established by the TR. Placing elements of "hot" pipelines at a distance of less than 150 mm from the floor shall not be permitted.
1952. Wellhead equipment and casing strings of underground wells shall withstand a pressure not less than 1.5 times the design maximum working pressure inside the wellbore.
1953. During the construction of underground wells, elements of their structure are stacked against one of the sides of the mine working. The distance between the stack and the opposite side of the mine working, or the most protruding dimension of equipment, utilities or rolling stock located in that cross-section of the mine working, and between two adjacent stacks, shall be not less than 1 m. The height of the stack shall be not more than 1.25 m.
1954. During the construction and repair of underground raise wells: screwing or unscrewing of drill pipes is carried out with the drill string secured in the clamping device of the drilling rig; the casing string is equipped with centralising devices, the design and installation locations of which are determined by the TR; before cementing begins, casing strings are anchored to the floor or to the opposite side of the mine working. Casing strings may be anchored to a thrust device braced against the sides and floor of the mine working; lowering of casing strings into the well and pumping of cement slurry into the annulus are carried out under the supervision of an oil mine worker. The presence in the work area of persons not connected with the performance of this work shall not be permitted.
1955. When carrying out work on the construction and repair of underground wells intended for injecting heat carrier, in areas where steam is being injected into the formation, the following is provided: the presence of blowout prevention equipment (BOP) at the wellhead; cessation of heat-carrier injection into adjacent wells not later than 10 days before the work begins; monitoring of the condition of the mine atmosphere according to the schedule specified in the work order; the presence at the workplace of a first-aid kit for providing first aid to workers; provision to drilling installation operators of communication equipment with the mine dispatcher of the oil mine, installed at a distance of not more than 100 m from the operating drilling rig on the intake air side; drilling of wells with flushing; diversion of the output of the underground well being drilled; the presence of thermal insulation ensuring that the surface temperature of the flow line, separator and receiving tank, where not installed within the rock mass, does not exceed 40 °C. During the work, the temperature of the liquid discharged from the well is monitored using a remote thermometer.
1956. During the construction and operation of underground wells, the following shall not be permitted: installing safety valves and instrumentation on operating equipment; installing shut-off devices between safety valves and equipment; installing gate valves without special locks on blowdown risers and on condensate collection and discharge lines; the presence, during pressure testing of the piping of drilling rigs and pumps, of persons not connected with the performance of this work at the test site; using lubricating oils not complying with the equipment's operating documentation.
1957. As sources of compressed air for well completion and operation, the mine-wide compressed air network and (or) mobile compressor units may be used.
1958. When restoring mine workings, the mouths of wells identified in them, the restoration of which is not intended, are plugged.
1959. The mouths of wells that are not in operation are sealed.
1960. Where significant accumulations of associated petroleum gas, water and oil under high pressure, as well as tectonic disturbances, are identified, measures are developed to ensure the safe performance of work on the construction, repair and operation of underground wells and wells drilled from the surface.
1961. Unscrewing of damaged pipes using fishing pipes is carried out using a drilling rig. Manual unscrewing of damaged pipes shall not be permitted.
1962. Construction of underground wells may be carried out in oil mines of both hazard groups for gases, from mine workings driven both through productive reservoir strata and through the enclosing rocks. Construction of wells in a production block is carried out in accordance with the design documentation and the TR.
1963. Before the construction of underground wells begins, the mine working is accepted for the construction of underground wells by a commission, the composition of which is determined by the organisational and administrative document of the oil mine. The result of acceptance is documented by a report drawn up in the form established by the organisational and administrative document of the oil mine. The acceptance report is kept at the oil mine for the entire period of operation of the oil mine.
1964. The presence of people in the zone of action of moving parts of operating drilling rigs shall not be permitted.
1965. Water pipelines are connected to drilling rigs with pneumatic and electric drives to ensure flushing of wells during drilling. Flushing of wells from a pressure pipeline may be carried out where drilling installations with hydraulic drive are used.
1966. During drilling, the drilling rig is anchored, and its running gear is braked.
1967. Drilling rigs with pneumatic drive are equipped with: on the compressed air line, within sight of the drilling installation operators - a pressure gauge, a valve regulating the air supply, and a safety valve with a compressed air discharge. Compressed air lines are pressure-tested to 1.5 times the working pressure. The safety valve shall trip at a pressure exceeding the maximum working pressure by 15 per cent; a pipe for discharging cuttings and aerated liquid, led out for connection to a cuttings trap at a distance of not less than 15 m from the drilling rig along the direction of ventilation air flow. The ingress of dust-laden air and aerated liquid into a drilling rig with pneumatic drive shall not be permitted.
1968. Drilling of a section of an underground well intended for setting a conductor casing in dry rocks with air flushing may be carried out with irrigation of the cuttings discharged from the well with water.
1969. When working with drilling rig jacks, the following shall not be permitted: using gaskets between jack heads and carriages or clamps; correcting the misalignment of jacks under load; holding the tool under tension with the hoisting rope while repositioning or aligning jacks; approaching jacks under load at a distance of less than 1 m; creating loads simultaneously with jacks and the rig winch; creating tension in the drilling tool with faulty pressure gauges on hydraulic jacks.
1970. Oil- and petrol-resistant hoses capable of withstanding a pressure not less than 1.5 times the maximum design working pressure are used on drilling rigs. During operation, the hose is secured to the fixed parts of the rig.
1971. The anchoring and serviceability of the drilling rig are checked by the drilling installation operators together with a worker of the structural subdivision at the start of the work shift and before lowering the casing string into the well. The condition of the support of the mine working at the location of the drilling rig is monitored by the senior drilling installation operator in the crew throughout the work shift, and by the worker of the structural subdivision to which that working is assigned - once per shift.
1972. When installing drilling rigs, the use of temporary support of the mine working and of pipelines as supports for anchoring the rig shall not be permitted.
1973. Operation of a drilling rig where the rig's anchoring is loosened, or the mine working support is compromised, or where rig parts or drilling tools run out of true, shall not be permitted.
1974. Where pumps serving a drilling rig are located outside the drilling chamber, a pressure gauge is installed on the discharge pipeline within sight of the drilling installation operator.
1975. An operating drilling rig is provided with: not less than two foam or carbon dioxide fire extinguishers; a set of brass or copper-plated auxiliary tools, as provided for in the manufacturer's operating documentation, for emergency work in a gas-contaminated environment; a set of emergency tools for capping steam and water blowouts.
1976. Preparation of flushing fluids may be carried out both on the surface of the oil mine and underground. Where flushing fluid is prepared underground: the mine working in which the flushing-fluid preparation unit is located has a closed drainage channel; flushing-fluid storage facilities are equipped, on the approach side, with barriers not less than 1 m high or with covers (decking).
1977. Replacement of the drill bit is carried out with the drill string fully stopped. The presence of people under a raised drill string shall not be permitted.
1978. The mouth of the well being drilled is fitted with wellhead equipment ensuring: passage of the drilling tool into the well and its withdrawal, tightness at the contact between the wellhead equipment and the drilling tool, and diversion of the output of the well being drilled into a cuttings tank.
1979. Before starting well cementing work, the following is checked: the serviceability of the safety valves and pressure gauges on the pump, and the pressure testing of the cementing unit to 1.5 times the design maximum pressure. The safety valve of the cementing unit is set to trip when the rated pressure is exceeded by 3.5 per cent.
1980. When cementing wells, the following shall not be permitted: the presence near cementing units of persons not connected with their operation; carrying out repair work on cementing units, cementing heads and pipelines under pressure.
1981. During the waiting-on-cement (WOC) period, the approach of people to the cemented well and passage along the mine working past it shall not be permitted, except in emergencies. Warning signs are installed on both sides of the cemented well. For the duration of the WOC period, the gate valve installed on the wellhead equipment of the cemented well is switched to the open position. Anchoring of the casing string of raise wells is carried out after the WOC period has elapsed.
1982. After completion of cementing, the occurrence in the cementing system of a pressure exceeding the working pressure by 10 per cent shall not be permitted.
1983. When carrying out work to retrieve drilling tools from wells and to seal fractures with a packer, people not connected with the performance of this work are moved out of the mine working where the well is located, to mine workings with intake air flow.
1984. Well completion in oil mines may be carried out only by liquid aeration in the well or by injecting compressed air into it. Well completion by bailing with a bailer and by swabbing (piston swabbing) shall not be permitted. Wells in mines are completed only after the installation and pressure testing of wellhead assemblies provided for by the design documentation for the period of well operation.
1985. The gate valve installed on the branch to the separator is fitted with "Open" and "Closed" indicators. The valve handwheel is located on the intake air side.
1986. When completing an underground well, tubing may be run and pulled provided that a gate valve with a crossover spool and nipple, capable of withstanding the maximum wellhead pressure, is available near the well. In the event of a kick (gas, oil and water influx) in an underground well, the gate valve with a crossover spool and nipple is closed at the wellhead, and further well completion work is stopped. Information on the kick in the underground well is transmitted to the mine dispatcher of the oil mine.
1987. Installations with centrifugal pumps are equipped with: an air cock on the pump housing with a discharge into a tank, intended for releasing air when priming the pump; a guard for the coupling; a device for priming the pump; a pressure gauge with a cock, a gate valve and a check valve, installed on the pump discharge pipeline within sight of the worker servicing the pump. Starting an unprimed centrifugal pump shall not be permitted.
1988. Piston, reciprocating and plunger pumps (hereinafter - positive-displacement pumps) are equipped, within sight of the worker servicing the pump, with: a pressure gauge mounted on the safety device; safety valves rated for a pressure exceeding the maximum working pressure by 10 per cent, with discharges directed into a receiving tank or a channel; starting gate valves on the discharge and unloading lines; check valves on the discharge lines. Starting positive-displacement pumps with the starting gate valves closed shall not be permitted.
1989. Discharge lines of centrifugal pumps, and the discharge lines and pressure compensators of positive-displacement pumps, are subjected to hydraulic pressure testing after installation or repair. This equipment shall withstand a pressure not less than 1.5 times the maximum working pressure developed by the pump. Carrying out hydraulic pressure testing using piston pumps shall not be permitted. The results of hydraulic pressure testing are documented by a report.
1990. In the pump chamber, the following are displayed in a visible place: a diagram of the pump piping and connections to pipelines and tanks; a diagram of the power supply to the pump chamber; a diagram of the automation of the pumping installations; the manufacturer's operating documentation for the pumping installations, and a gate-valve control table.
1991. Pumping installations are inspected and prepared for operation at the start of the work shift. Before inspection and preparation for operation, a warning sign is displayed on the starting apparatus, and pumping installations controlled automatically or remotely are switched to manual control. Leaving operating pumping installations without supervision shall not be permitted. After completion of the inspection and preparation of the pumping installation for operation, its control is switched from manual control to automatic or remote control.
1992. When starting and stopping pumping installations manually, the position of the corresponding gate valves on the discharge and unloading lines is checked.
1993. During pump operation, monitoring of their tightness is carried out. Leaks in glands, mechanical seals of pumps, and pipeline connections are eliminated.
1994. Pump bearings are supplied with lubricant in the quantity established by the manufacturer's operating documentation. Overheating of pump bearings above the values established by the manufacturer's operating documentation shall not be permitted.
1995. When switching from an operating pump to a standby pump, the correct opening and closing of the gate valves of the operating and standby pumping installations, and the readiness of the standby pump for starting, are checked.
1996. When pumping liquids with piston pumps, cessation of supply is carried out after the pump is stopped or the flow is switched to another tank.
1997. During breaks in installation or dismantling work, leaving unsecured units of pump equipment being installed or dismantled shall not be permitted. Using the foundations of pump units as supports for lifting devices shall not be permitted.
1998. Methods of operating underground production wells in oil mines are determined by the design documentation, the documentation for conducting oil production work, and the TR.
1999. Acceptance of production blocks for development is carried out by a commission, the composition of which is determined by the organisational and administrative document of the oil mine. The result of acceptance is documented by a report drawn up in the form established by the organisational and administrative document of the oil mine. The acceptance report is kept at the oil mine for the entire period of operation of the oil mine.
2000. During the operation of underground wells, the parameters of the heat carrier, the mode of heat-carrier injection into the formation through injection wells, and the monitoring of the operation of injection wells shall comply with the technological modes for injecting heat carrier into the formation through injection wells, contained in the design documentation, the documentation for conducting oil production work, and the TR.
2001. Servicing of operating injection and production underground wells in oil production areas is carried out by a crew of workers consisting of not less than two persons, following a shift route. The locations and frequency of monitoring mine atmosphere parameters by persons servicing operating injection and production underground wells are specified in the work order.
2002. When killing an underground well, in the mine working from which it was drilled, a set of emergency tools for capping water blowouts and a set of brass or copper-plated auxiliary tools is provided.
2003. Injection and production wells are equipped with individual or group shut-off devices allowing the heat-carrier flow rate and output offtake to be regulated.
2004. In structural subdivisions carrying out oil production work, a log of the results of tests, inspections, checks and repairs of "hot" pipelines and the mouths of injection wells is kept, in the form established by the organisational and administrative document of the oil mine.
2005. Persons responsible for the ten-day inspection and monitoring of the condition of "hot" pipelines and injection wells are appointed by the organisational and administrative document of the oil mine. The results of the ten-day inspection and monitoring are entered in the log of the results of tests, inspections, checks and repairs of "hot" pipelines and the mouths of injection wells.
2006. An injection well, or a group of such wells, is equipped with instruments for measuring the pressure and temperature of the heat carrier supplied to them. The wellhead equipment of injection wells intended for injecting water at a temperature below 40 °C into the formation is fitted with pressure gauges and flow meters. A single pressure gauge and flow meter may be installed for a group of injection wells.
2007. Where corrosive formation water is used as the heat carrier, pump equipment made of corrosion-resistant high-strength materials is used for pumping it.
2008. Before installation at the wellhead, the wellhead assembly of injection wells, in assembled form, is pressure-tested to a trial hydraulic pressure. Before commissioning, the pump piping is subjected to pressure testing and shall withstand a pressure not less than 1.5 times the maximum working pressure developed by the pump. The results of pressure testing are documented by a report.
2009. Shut-off valves are installed on branches from an underground main steam pipeline to a group of injection wells.
2010. Monitoring of the process of injecting heat carrier into the formation is carried out by the oil production operator. The mode of injecting heat carrier into the formation through injection wells is determined by the head of the structural subdivision carrying out oil production work.
2011. Swabbing (piston swabbing) and bailing in production wells may be used after their first workover. Operation of production wells by swabbing or bailing after their completion may be carried out only in depleted productive formations.
2012. In compressor (gas-lift) operation, the working agent used is compressed air from the mine-wide network, and in oil mines of hazard group I for hydrocarbon gases, also from mobile compressor units.
2013. On compressed-air lines from mobile compressors, oil-water separators equipped with automatic or manual blowdown are installed at the lowest points. Blowdown lines are led out into mine workings with return air flow and directed into a channel. On compressed-air lines from mobile compressors, check valves whose design prevents the accumulation of oil in them are installed between the oil-water separators and the distribution manifolds.
2014. Intake air receivers of mobile compressors are arranged in special chambers or mine workings and have filters for cleaning the air of mechanical impurities. A mobile compressor is stopped if there is a possibility of hydrocarbon gases and vapours of liquid hydrocarbons entering its intake air receiver.
2015. When wells are being purged, the pressure and temperature on the compressed-air lines from mobile compressors are monitored. Purging of intermediate coolers shall not be permitted.
2016. To measure the buffer pressure and the annulus pressure at production wells, branch connections with three-way cocks for connecting pressure gauges are permanently installed.
2017. The feasibility of using surface-active agents in the compressor operation of production wells is determined by the process regulations.
2018. Where a group of wells served by a single submersible hydraulic piston pump unit is operated, an electric contact pressure gauge and a safety valve are installed on the pump discharge line, the outlet of which is led below the level of the pump's working fluid in the tank.
2019. Before the submersible hydraulic piston pump unit is started, the pump discharge line with all branches to production wells, the wellhead equipment and the casing strings of production wells are tested and shall withstand a pressure exceeding the maximum working pressure developed by the pump by at least 1.5 times.
2020. The hydraulic piston pump unit is started after the electric contact pressure gauge has been checked for serviceability, with the shut-off devices on the pump suction and discharge lines and on the bypass line open. Pressure in the discharge system is built up after normal operation of the equipment installed in the oil transport process line has been established.
2021. When the hydraulic piston pump unit is stopped, the pressure in the discharge pipeline is reduced to atmospheric.
2022. Hydraulic piston pump units are equipped with hoists for running in and pulling out. Before hydraulic piston pump units are run in or pulled out, the pressure at the wellheads of production wells is reduced to atmospheric.
2023. Discharge of the gas-air mixture from air-lift wells is carried out into a dedicated gas vent line.
2024. Hydraulic piston pump units are attended by not fewer than two workers.
2025. Before the wellhead equipment is dismantled, the pressure in the annular space and the annulus of wells is reduced to atmospheric.
2026. Cutting of pipes in a well is performed under the direction of an employee of the oil mine.
2027. Leaving a string of pipes suspended during breaks in pipe or rod running or pulling operations shall not be permitted.
2028. When a pipe is laid out onto the platform or floor, its free end is placed on a sliding support. Pipes and rods are laid out and pulled one pipe or rod at a time.
2029. When sand plugs are cleaned out with a bailer, a hook that does not produce sparks on friction, a knock-out box with a "cushion", a drainage trough and a hose from the water line are used. Emptying the bailer directly onto the floor of the working platform shall not be permitted. Cleaning sand plugs with a bailer in flowing wells and (or) wells discharging gas or vapour shall not be permitted.
2030. A pressure gauge and a safety device are installed on the pump of the flushing unit. The discharge line from the safety device is directed into a ditch and secured.
2031. When plugs are flushed out of wells from which blowouts are possible, a blowout preventer gate valve is installed at the wellhead, or a sealing device is installed on the flushing pipes. To flush out plugs in wells, a flushing fluid with a specific gravity providing hydrostatic pressure of the fluid in the well equal to the formation pressure is used.
2032. Cleaning of pipes from paraffin deposits is carried out by steaming.
2033. A safety valve with an outlet preventing the possibility of scalding people with steam is provided on the steam pipeline.
2034. During steaming of a well, the presence of people near its wellhead shall not be permitted.
2035. The hose for supplying steam into the tubing is fitted with special end fittings.
2036. Well workover operations are carried out under the direction of an employee of the oil mine.
2037. When one of the injection wells in a chamber or gallery is under repair, the other injection wells emerging from that mine working are shut down.
2038. The design, installation and operation of surface and underground mine air compressor units, air pipelines and air receivers, oil-and-water separators and aftercoolers are carried out in accordance with the requirements of the rules for the design and safe operation of stationary compressor units established by the Federal Environmental, Industrial and Nuclear Supervision Service (Rostechnadzor).
2039. The technology of the complex for the gathering, transport and treatment of oil, associated petroleum gas and water in the underground mine workings of oil mines ensures: gathering of the production of production wells into tanks of the production blocks; separation of oil gases (gas condensate) in gas separators and their discharge via the mine's gas-gathering network to the mine surface, for Hazard Group II mines in respect of hydrocarbon gases; removal, in the collecting tanks of the production blocks, of coarse-grained and medium-grained mechanical impurities from the production of production wells; closed transport of the oil-water emulsion from the tanks of the production blocks to district oil traps and central oil traps; settling and separation of oil and water, with their discharge into tanks intended for this purpose; closed transport of oil directly to the oil treatment plant on the mine surface; transport of surplus water from the oil traps to water sumps, with subsequent pumping to treatment facilities on the mine surface.
2040. For Hazard Group I mines in respect of hydrocarbon gases, open gathering of the production of production wells into tanks of the production blocks is permitted.
2041. When wells are drilled with hydraulically driven rigs or with flushing in field drifts, discharge of water into drainage ditches is permitted, provided that the water is conveyed via the drainage ditches to tanks intended for its collection.
2042. Drainage ditches in the mine workings of oil mines of Hazard Group II in respect of hydrocarbon gases are used to collect and convey fluid discharged from the rock.
2043. The following shall not be permitted: placing oil traps and oil pumping stations in dead-end mine workings; leaving oil pooled on pump foundations or under the foundation frame of equipment and mechanisms.
2044. For pumping and transporting oil, gas and gas condensate, the use of equipment and pipes made of dielectric materials with a specific volume electrical resistivity exceeding 109 Ω·m shall not be permitted.
2045. Gasket materials with a smoulder temperature of not less than 350°C are used for flanged joints of mine air pipelines.
2046. The lining of tanks for the gathering and treatment of oil and water, and the gangways, handrails, ladders, catwalks and platforms in these tanks, are made of non-combustible and spark-proof materials.
2047. Receiving tanks for water collection are provided in production workings into which water may enter from the mine workings of the haulage level. The volume of the receiving tanks is calculated taking into account the maximum inflow of water from the mine workings of the haulage level. The receiving tanks are equipped with a duty pump unit and a standby pump unit, each of which ensures pumping-out of the maximum daily inflow of fluid into the production working within not more than 20 hours.
2048. In oil mines of Hazard Group II in respect of hydrocarbon gases, the use of open tanks for the gathering and treatment of oil and water shall not be permitted. Tanks for the gathering and treatment of oil and water in production blocks are made airtight and fitted with pipelines for conveying gases and vapours released in them to the degassing network.
2049. Sight windows of oil settling tanks and oil gathering tanks in oil mines of Hazard Group II in respect of hydrocarbon gases are made airtight, of a material that also ensures visibility through the sight windows.
2050. The heating temperature of oil in the tanks of the gathering and treatment system is determined by the project documentation. Heating of oil is carried out with water steam or hot water.
2051. Pump units (hydro-elevators) with a float system on the pump suction pipeline are installed in the tanks of oil traps.
2052. Manual sampling of oil from oil gathering tanks is carried out while the fluid in them is in a "quiescent state".
2053. Work in oil tanks is permitted to be carried out after they have been cooled with water to the ambient air temperature. Before cleaning work begins, the tanks are ventilated, the content of hydrocarbon gases, vapours of liquid hydrocarbons, carbon monoxide, carbon dioxide and oxygen in them is determined using portable instruments, and air samples are taken for subsequent analysis in a gas-analysis laboratory. Oil tanks are ventilated while air samples are taken and while cleaning and repair work is performed in them. Air sampling and cleaning and repair work in oil tanks are carried out under the direction of an employee of the oil mine. Air sampling and cleaning and repair work in oil tanks are performed by a worker wearing PPE and a hose-type breathing apparatus, or connected to a compressed-air breathing apparatus. The free end of the hose of the hose-type breathing apparatus is secured in a zone with clean air. On completion of cleaning or repair of an oil tank, before its hatches are closed, the person responsible for carrying out that work shall personally ascertain that there are no people, tools or materials in the tank.
2054. During opening, air sampling, cleaning or repair, and closing of an oil tank, the presence of people in the return air current from it shall not be permitted.
2055. The design, construction and operation of mine pipelines are carried out in accordance with the requirements of these Rules.
2056. Mine pipelines are installed (suspended) on supports (hangers), the design of which is determined by the project documentation and allows displacement of the pipes in the longitudinal and transverse directions.
2057. In vertical mine workings, supports that reduce the vertical loads on pipelines are used.
2058. Devices for draining fluid are installed at the upper and lower parts of vertical and inclined pipelines.
2059. Pressure water pipelines and compressed-air pipelines are laid in vertical mine workings equipped with cage hoisting. Placing a pipeline with a pressure of 6.4 MPa in it opposite the entrance to and exit from the cage shall not be permitted. Oil pipelines for delivering oil out of the mine and pipelines for supplying heat-transfer fluid into the oil mine are laid in boreholes.
2060. During the construction and reconstruction of oil mines, mine workings parallel to the haulage drift and the ventilation drift are provided, intended for laying steam pipelines along them and for passing the return air current.
2061. When pipelines are placed in the workings of production inclines and panels: in the travelling roadway of the incline or panel, a compressed-air pipeline and a pressure pipeline to the hydro-elevators and the drilling rig are laid; in the ventilation working of the incline or panel, a heat-transfer fluid pipeline, a pipeline for pumping out the production of production wells, a discharge pipeline of the hydro-elevators, and a degassing pipeline are laid.
2062. Pipelines intended for transporting gases and water steam are placed in the upper parts of mine workings. Pipelines used for transporting clean fluids, mixtures thereof, and mixtures of fluids with mechanical impurities, are placed on the floor or in the lower part of the mine working. Free gaps between pipelines are provided for carrying out maintenance, repair and replacement work on them. The width of the passages between the most protruding parts of the pipelines and the maximum dimensions of machines, equipment, mechanisms and transport vessels moving along the working shall be not less than 0.7 m, with a passage height of not less than 1.8 m. The width of the clearance between pipelines and the dimensions of rolling stock shall be not less than 0.25 m. The laying of pipelines in mine workings driven through rock prone to heaving shall not be permitted.
2063. Pipeline drifts are equipped with rail tracks made of rails not lighter than type P18.
2064. Non-return valves are installed on the discharge pipelines of pumps laid in inclined mine workings, vertical shafts and boreholes.
2065. Safety valves installed on equipment for the gathering and transport of oil, gas and water, and on pipelines, are set to a trip pressure exceeding the working pressure in the equipment or pipeline by not more than 10 per cent of the working pressure.
2066. The serviceability of safety, control and shut-off valves is checked in accordance with a schedule approved by the technical manager of the oil mine. Cast-iron valves are protected against bending stress. Shut-off valves on pipelines that do not have a mechanised drive are opened with special brass or copper-plated keys (hooks).
2067. Pipelines are checked for strength and tightness after installation and major repair. Before valves are fitted and pressure testing is carried out, the pipeline is purged or flushed.
2068. After installation or repair, mine pipelines are subjected to testing as follows: gas pipelines and air pipelines - to pneumatic testing at a pressure equal to the working pressure in the mine compressed-air network, but not less than 0.3 MPa; field pipelines - to hydraulic testing carried out in accordance with the requirements of Chapter XXXIII of these Rules. The value of the test hydraulic pressure for pipelines (other than "hot" pipelines) shall exceed the working pressure by 25 per cent, but by not less than 0.2 MPa. Mine "hot" pipelines are tested at a pressure exceeding the maximum working pressure by 1.5 times, but by not less than 0.5 MPa.
2069. Testing (pressure-testing) work on pipelines is carried out under the direction of an employee of the oil mine. In mine workings through which people may pass to the pipeline under test, watch posts are stationed or warning signs are posted.
2070. Unused sections of gas pipelines and oil pipelines are disconnected from the operating networks and closed with steel blank plugs. In mine workings, previously used oil pipelines and gas pipelines are permitted to be used as water pipelines after their reconstruction, treatment and testing.
2071. Inspections of underground mine pipelines are carried out: daily - by foremen of the oil production, ventilation and safety engineering sections; monthly - by heads or deputy heads of structural subdivisions; quarterly - by the chief mechanical engineer of the oil mine or a person appointed by him, and by the head of the in-mine transport service of the oil mine or a person appointed by him; once every six months - by the technical manager of the oil mine or a person appointed by him. A log recording the results of pipeline tests, inspections and repairs, drawn up in the form established by the organisational and administrative document of the oil mine, is kept at the oil mine.
2072. At an oil mine using thermal mine technology, a mine working plan is drawn up showing the layout of the trunk and distribution "hot" pipelines. On the plan, for all operating trunk and distribution "hot" pipelines, the following are indicated: the sequential number of the pipeline; the type of medium transported; the pressure and temperature of the medium transported; the length of pipeline sections, indicating the diameters and wall thicknesses of the pipes; the location of expansion joints and valves, indicating their types and numbers, and of drain and purge devices; the type and design of the thermal insulation coating; the laying methods; and the non-operating and disconnected sections of pipelines. Changes are entered into the plan by an employee of the oil production section within 24 hours from the moment of the actual change in one or more characteristics of the trunk and distribution "hot" pipelines.
2073. Places where pipelines emerging from steam-injection wells drilled from the day surface into underground workings connect to the trunk pipelines for transporting heat-transfer fluids are equipped with pressure gauges with cocks and thermometers. If water steam is used as the heat-transfer fluid, devices for draining condensate are also installed at these places. Monitoring of the condition and operation of the instruments, and the draining of condensate from pipelines, are carried out by employees of the oil production (thermal production) structural subdivisions in accordance with a schedule approved by the technical manager of the oil mine. If the heat-transfer fluid parameters established by the project documentation or the process regulations are exceeded, this shall be reported immediately to the mine dispatcher of the oil mine or to the head of the oil production (thermal production) structural subdivision.
2074. Thermal insulation of pipelines and wellhead equipment of wells is made of non-combustible materials that are non-toxic when exposed to high temperature and on contact with oil, water and the mine atmosphere.
2075. Flanged joints of "hot" pipelines laid in mine workings are fitted with removable thermal insulation to provide convenient access to them during inspections and repairs.
2076. Shut-off valves on "hot" pipelines are installed in well-ventilated places accessible for inspections and repairs. Where necessary, ladders, crossings and platforms are provided for access to them. Shut-off valves on "hot" pipelines are numbered, starting from the source of the heat-transfer fluid or from the pump unit.
2077. Sections of "hot" pipelines laid along the floor of a mine working and in ditches are fitted with insulation for protection against corrosion.
2078. At the lowest points of each section of the steam pipeline that can be isolated by gate valves, fittings with shut-off valves and branches to a drainage ditch, intended for draining condensate from the steam pipeline, are provided.
2079. All "hot" pipelines are covered with thermal insulation. The surface temperature of the thermal insulation during operation of "hot" pipelines shall not exceed 40°C.
2080. In places where dripping of oil and water is observed, "hot" pipelines are protected with casings or canopies.
2081. Fixed supports are installed at the points where branches leave the trunk "hot" pipelines.
2082. U-shaped expansion joints and arches of "hot" pipelines, at points of crossing through mine workings, are fixed to elements of the mine working support or laid in channels.
2083. On trunk "hot" pipelines near steam-injection wells, at the entrances to and exits from mine workings in which heat-transfer fluid is being injected or hot production of production wells is being extracted, placards are posted: "Danger! Steam (hot water) injection!"
2084. In mine workings in which heat-transfer fluid is being injected or hot production of production wells is being extracted, alcohol thermometers are installed in the return air current.
2085. When "hot" pipelines are started up, all people are withdrawn from the mine workings in which the pipelines are laid to mine workings in which no "hot" pipelines are being started up. The start-up of "hot" pipelines is carried out on the written instruction of the head of the oil production (thermal production) structural subdivision, agreed with the head of the aerological safety service.
2086. Repair of pipelines for heat-transfer fluids is carried out in compliance with measures ensuring industrial safety and safety during repair work, approved by the technical manager of the oil mine: disconnection of the section of pipeline under repair from the injection wells and from the source of the heat-transfer fluid; reduction of the pressure in the section of pipeline under repair to atmospheric. Reduction of pressure in the pipeline system for heat-transfer fluids is carried out only at the ground surface.
2087. An external inspection of mine "hot" pipelines is permitted to be carried out without removing the insulation. The results of the inspection are entered in the log recording the results of tests, inspections, checks and repairs of "hot" pipelines and the wellheads of steam-injection wells.
2088. Carrying out repair work on injection pipelines and the shut-off devices on them shall not be permitted during injection of heat-transfer fluid into the formation, or when the temperature of the pipe walls exceeds 40°C.
2089. The system for the gathering and transport of associated petroleum gas and gas condensate provides for the collection and conveyance of gaseous components to the ground surface, and for the removal of gas condensate from gas pipelines, its collection in tanks and its removal from the oil mine.
2090. The installation of several gas separators in a single mine working is permitted in the following cases: drilling and operation of production wells are conducted simultaneously in the mine working; the wells operated in the mine working cannot be served by a single gas separator because of its low throughput capacity.
2091. Gas pipelines of the oil degassing network are laid in mine workings with a return air current.
2092. The collection and removal of gas condensate from mine gas pipelines are carried out in accordance with documentation approved by the technical manager of the oil mine.
2093. A condensate collection point is set up in a mine working with a return air current, at the point where the gas pipeline joins the gas discharge well.
2094. Transport vessels used for conveying gas condensate are equipped with braking devices allowing the locomotive driver (of a battery electric locomotive or a gyro-locomotive), without leaving the cab, to brake the transport vessel while it is moving and to bring it to a complete stop when it stops and (or) is stationary.
2095. The brake shoes of transport vessels used for conveying gas condensate are made of a material that does not produce sparks in operation.
2096. In the mine workings of oil mines, main drainage units (MDU), district drainage units (hereinafter - DDU), pumping stations and mobile pumping stations are provided in accordance with the project documentation. Drainage units are equipped with automatic or remote automated control apparatus.
2097. Drainage units, other than units located in incline blocks, are equipped with not less than two sumps that are not interconnected. A DDU is permitted to be constructed without special chambers and with a single sump where the water inflow is less than 50 m3/h. Sumps of an MDU shall fill in not less than 4 hours, and sumps of a DDU in not less than 2 hours.
2098. In oil mines whose mine workings may receive large volumes of water within a short interval of time (hereinafter - water inrushes), measures are provided to prevent flooding of mine workings during water inrushes. In oil mines in which water inrushes into mine workings are possible, drainage units are enclosed by watertight bulkheads.
2099. MDUs and DDUs are equipped with duty and standby pump units. Where the water inflow exceeds 50 m3/h, an MDU is equipped with not less than three pump units. The number of pump units at oil mines with a water inflow exceeding the capacity of a single pump unit is selected in accordance with Appendix No. 26 to these Rules. The capacity of the duty and standby pump units, or of a group of simultaneously operating duty units, shall ensure pumping-out of the maximum daily water inflow within not more than 20 hours.
2100. An MDU is equipped with not less than two drainage pipelines, one of which is a standby. The throughput capacity of each pipeline shall correspond to the capacity of the duty pump unit or of a group of simultaneously operating duty pump units. Shut-off valves are installed on the pipelines in an MDU, ensuring that water can be pumped out while repair work is carried out on one pump unit. The laying of pipelines of drainage units operating at a pressure exceeding 6.4 MPa in vertical shafts, at sections opposite the doors of the hoisting installation cage, shall not be permitted. Pipelines of an MDU shall be tested after their installation, and not less often than every 5 years of operation, at a pressure exceeding the working pressure by not less than 1.25 times.
2101. The maximum and normal inflows of water entering the oil mine are determined annually, together with its chemical analysis. In oil mines with water inflows having a pH of less than 6, drainage equipment is made of acid-resistant materials. Where water inflows have a pH > 6, the use of drainage equipment in the standard version for neutral waters is permitted.
2102. The procedure and frequency for inspecting and checking the operability of drainage units are established by the organisational and administrative document of the oil mine. Instrumental checking of operability is carried out not less often than once a year.
2103. During the driving of mine workings, standby pump units are permitted not to be connected to the pipeline where they are located next to the duty pump units.
2104. During the driving of vertical mine workings, standby pump units are placed at their collar.
2105. The use of electrical networks with a solidly earthed neutral of power sources and transformers shall not be permitted in oil mines.
2106. Remote, telemechanical and automatic control of electrical equipment with a voltage above 1140 V is permitted only where automatic interlocking is provided that prevents the switching-in of power transmission lines and electrical equipment with reduced insulation resistance to earth.
2107. The high-voltage disconnectors of mobile substations and transformers are electrically interlocked with the packaged switchgear units (hereinafter - PSG) from which they are supplied.
2108. Mobile substations and transformers installed in mine workings with a return air current in gas-hazardous oil mines are connected to the electrical network through PSG with remote control via intrinsically safe circuits and with an earth-leakage protection unit (hereinafter - ELPU) monitoring the insulation of the network to earth.
2109. Telemechanical control of the PSG from the control panel of the mine dispatcher (operator) of the oil mine is organised in accordance with the project documentation. PSG units are installed in chambers ventilated with fresh air. For switching in the district switching point and electrical equipment located in mine workings with a return air current, switching apparatus with an ELPU is used.
2110. Control of face machines, equipment and hand-held electric tools in gas-hazardous oil mines is carried out via intrinsically safe circuits. To supply voltage to face machines in the mine workings of gas-hazardous oil mines, magnetic starters and magnetic control stations with intrinsically safe control circuits are used. The use of single-button control posts for controlling magnetic starters shall not be permitted, except where such posts are used solely for switching them off. After face machines have finished operating, the disconnectors of the magnetic starters are switched off and their handles are locked. Before repair and auxiliary work is performed on the moving parts of face machines, the voltage is removed and measures preventing the starting of face machines are taken.
2111. Parallel connection of mobile substations and transformers for supplying a switching point to which power consumers with a total capacity exceeding the capacity of each of the mobile substations and transformers are connected shall not be permitted. Stationary switching points are connected to transformer substations by armoured cables.
2112. Markings are applied to starters, automatic circuit-breakers, PSG units and transformers, indicating the electrical equipment connected to them and the trip-current setting of the maximum-current relay or the rated current of the fuse. Distribution, starting and measuring apparatus is sealed.
2113. The power supply and use of electrical equipment in dead-end mine workings of gas-hazardous oil mines ventilated by an auxiliary ventilation fan (AVF) shall comply with Appendix No. 27 to these Rules.
2114. The following shall not be permitted: servicing and repairing electrical equipment and electrical networks without instruments and tools intended for these purposes; servicing electrical equipment without protective equipment used in electrical installations, except for electrical equipment with a voltage of 42 V and below, electrical equipment with intrinsically safe circuits, and telephone communication apparatus; operating electrical equipment with faulty explosion-protection means, interlocks, earthing or protection devices, with impaired control or protection circuits, or with damaged cables; repairing electrical equipment and cables that are energised, or connecting and disconnecting spark-hazardous electrical equipment and electrical measuring instruments while energised, except for devices with a voltage of 42 V and below in oil mines that are not gas-hazardous, and the same devices with intrinsically safe circuits in gas-hazardous oil mines; keeping unused electrical networks energised, except for standby networks; opening the enclosure covers of explosion-proof electrical equipment without first removing the voltage from the compartment of the enclosure being opened and, in gas-hazardous oil mines, without monitoring the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons; removing signs, markings and seals from electrical apparatus by workers not authorised to perform such actions; switching in an electrical network containing cables with damaged sheaths or damaged core insulation.
2115. The following underground power supply diagrams are drawn up at the oil mine: a general schematic diagram of the underground power supply of the oil mine (hereinafter - the general schematic diagram); a diagram of the underground cable network, shown on the diagram of the mine workings of the oil mine or on the mine working plans of each level (hereinafter - the underground cable network diagram); power supply diagrams of individual mine workings or complexes thereof served from each operating district substation, shown on the mine working plans (hereinafter - the power supply diagrams of individual mine workings); a diagram of the mine underground communication and signalling system. Changes in the composition and operating conditions of electrical networks and electrical equipment, and of the systems and apparatus of mine underground communication, are reflected in the underground power supply diagrams and in the operational record-keeping documentation on communication and signalling not later than within 24 hours from the moment of the actual change in the composition and (or) operating conditions of the electrical networks, electrical equipment or mine underground communication apparatus.
2116. The general schematic diagram shows: the mine cable network indicating rated voltage values, cable types, lengths and cross-sections; distribution and protective apparatus; current-consuming devices indicating their power; two-phase short-circuit current values for a fault at the electrically most remote point of the protected section of the network; the trip current settings of maximum current protection devices and the rated currents of fuse links; and three-phase short-circuit current or power values on the busbars of the RP-6 switchgear and section underground substations. For oil mines having a branched system of mine workings and a large number of electrical equipment items, the general schematic diagram may be drawn up in separate parts showing, in addition, the stationary electrical equipment, including section transformer substations, and the electrical equipment of production and development sections.
2117. The diagrams of the underground cable network show the high-voltage and low-voltage cable network, the outlines and names of chambers for electrical equipment, the lighting network, the locations of telephone sets, and the directions of air currents.
2118. The general schematic diagram and the diagram of the underground cable network are drawn up once every six months and approved by the technical manager of the oil mine.
2119. The diagrams of power supply to individual mine workings show: the cable network from section substations to current-consuming devices indicating cable types, lengths and cross-sections; distribution and protective apparatus; current-consuming devices; the calculated minimum two-phase short-circuit current values for a fault at the electrically most remote point of the protected section of the network; the trip current settings of maximum current relays and the rated currents of fuse links; and the directions of air currents. The diagrams of power supply to individual mine workings are drawn up during their driving and once during their operation, and are approved by the chief power engineer (chief mechanical engineer) of the oil mine.
2120. In the mine workings of gas-hazardous oil mines, and in surface buildings adjoining shafts with an outgoing air current from such mines, explosion-protected mine electrical equipment is used.
2121. In the mine workings of gas-hazardous oil mines, haulage by trolley locomotives shall not be permitted.
2122. Work on the adjustment, testing, repair, inspection and overhaul of explosion-protected mine electrical equipment is carried out in accordance with the manufacturer's operational documentation and the procedure established by the organisational and administrative document of the oil mine, with observance of measures ensuring the safety of the performance of such work, and where the total concentrations of hydrocarbon gases and liquid hydrocarbon vapours in the mine atmosphere do not exceed the maximum permissible total concentrations of hydrocarbon gases and liquid hydrocarbon vapours given in Appendix No. 15 to these Rules.
2123. The insulation testing and fault location of power cables laid in the mine workings of gas-hazardous oil mines are carried out where the total concentrations of hydrocarbon gases and liquid hydrocarbon vapours do not exceed the maximum permissible concentrations given in Appendix No. 15 to these Rules.
2124. Standard-design mine electrical equipment complying with the requirements of the legislation on technical regulation may be used in the mine workings of oil mines not hazardous by gas. In oil mines hazardous by gas, the following may be used: standard-design mine electrical equipment in shafts and pit-bottom workings with a fresh air current, except where such mine workings have gas blower emissions; standard-design mine electrical equipment and general-purpose electrical equipment in the premises of fan and heater installations on the mine surface, provided that mine air does not enter such premises; general-purpose electrical equipment in the electrical machine rooms of hoisting installations located at headframes of shafts with an outgoing air current, provided that mine air does not enter such premises.
2125. The installation and operation of standard-design mine electrical equipment and general-purpose electrical equipment are carried out in accordance with documentation approved by the technical manager of the oil mine and containing: a list of actions ensuring the safe operation of the electrical equipment; a power supply diagram; a ventilation diagram of the mine workings in which the electrical equipment is installed, indicating the ventilation devices ensuring ventilation with a fresh air current; the locations of sensors for monitoring the total concentrations of hydrocarbon gases and liquid hydrocarbon vapours; and a list of electrical equipment with technical specifications.
2126. Work on the adjustment, testing, repair, inspection and overhaul of standard-design mine electrical equipment and general-purpose electrical equipment is carried out in accordance with the manufacturer's operational documentation and the procedure established by the organisational and administrative document of the oil mine, with observance of measures ensuring the safety of the performance of such work.
2127. Platforms are provided on both end sides of mobile substations installed in haulage workings, and, on the higher-voltage side, wooden grilles on insulators. A safety device preventing rolling stock from entering the section of rail track on which the substation is installed is installed at the mobile substation. Warning signs are posted at the approaches to the substation.
2128. Electrical equipment shall be protected against the ingress of oil and water onto it.
2129. The switching-on or switching-off of electrical equipment installed in the mine workings of oil mines that has enclosed housings and blocking devices in their normal position ensuring their explosion safety may be carried out by an employee alone, provided that the employee holds the appropriate electrical safety group, has been granted admission to operate the equipment in question, and the parameters of the mine atmosphere comply with the requirements of paragraph 1731 of these Rules.
2130. The following voltage is used to supply electrical equipment: not exceeding 10 000 V - for stationary electrical equipment, mobile substations and transformers; not exceeding 1140 V - for mobile electrical equipment; not exceeding 127 V - for hand-held electric machines and tools; not exceeding 60 V - for underground public address and signalling circuits, remote control circuits and switchgear signalling circuits, if none of the conductors of such circuit is connected to earth; not exceeding 42 V - for electrical equipment remote control circuits.
2131. The use of circuits under which electrical machines are started, or voltage is applied to them, simultaneously from two or more control panels shall not be permitted. This requirement does not apply to control circuits for local ventilation fans (VMP).
2132. The short-circuit power in the underground network of an oil mine is limited to a value corresponding to the rated characteristics of the electrical equipment installed in the oil mine and to the cross-section of the cables, and shall not exceed 50 MVA. An increase in the short-circuit power in underground networks intended to supply electrical equipment of pit-bottom workings may be permitted where this is consistent with their characteristics and cable cross-section. The breaking capacity of general-purpose switchgear circuit-breakers shall be twice the short-circuit power of the network.
2133. Chambers and recesses for electrical equipment in mine workings (hereinafter referred to as "chambers and recesses"), irrespective of the strength of the rock in which such workings are driven, are supported with permanent non-combustible support, the safety factor of which shall be not less than 2. The following shall not be permitted: installing electrical equipment in workings without support, or workings supported with temporary or rock-bolt support; carrying out repair and enlargement of workings where operating or de-energised electrical equipment is present at the location of such work. Entrances not less than 1.5 m wide and not less than 1.8 m high are provided to chambers and recesses.
2134. For the installation and maintenance of electrical equipment in chambers and recesses, passages shall be provided of a width not less than: 0.8 m between machines and apparatus; 0.5 m between machines, apparatus and the walls of the chamber; 1.0 m between the mesh guard of a recess and the apparatus installed in it. Electrical equipment may be installed close together and to the wall of the chamber or recess, provided that access to it from the rear and sides for maintenance, installation and repair is not required. Where a recess has no mesh guard installed, the electrical equipment is installed in the recess at a distance of 0.5 m from its mouth. Obstruction of passages in chambers and recesses shall not be permitted.
2135. In the mine workings of the pit bottom, electrical equipment in main ventilation fan (GVU) chambers and central underground substations (hereinafter referred to as "CUS") is installed in such a way that the parts of the electrical equipment accessible to the ingress of oil and water to live parts are located at a height of not less than 1.0 m above the rail head level of the pit bottom at the point of its junction with the shaft. The requirements of this paragraph do not apply to sunken chambers with automated liquid pumping.
2136. The floor level of CUS and GVU chambers shall be not less than 0.5 m above the rail head level of the pit bottom. GVU chambers may be arranged below the level of the pit bottom, provided that measures ensuring the safety of work in such chambers are developed and implemented.
2137. In chambers and recesses located outside the oil-bearing seam and equipped with apparatus and machines containing oil, the construction of oil-collecting pits shall not be permitted. A sill not less than 0.1 m high is provided in chambers and recesses. Oil leaks are eliminated, and spilled oil is removed. In chambers and recesses located within the oil-bearing seam, electrical equipment is installed on foundations or stands made of non-combustible materials. The height of the foundations shall exceed the floor level of the chamber or recess by not less than 0.2 m. The floor is made of non-combustible materials and has a slope of not less than 20 per cent towards the channel in the chamber or towards the mouth in the recess. The accumulation of oil in chambers and recesses shall not be permitted.
2138. In chambers more than 10 m long, two exits are provided, located in the parts of the chamber most distant from each other.
2139. In chambers where oil-filled electrical equipment is installed, solid doors are provided. In other chambers, lattice doors with a locking device are provided. The doors of chambers without permanent attending personnel are kept closed.
2140. A notice reading "Unauthorised entry prohibited" is posted at the entrance to the chamber, and warning signs are installed in a conspicuous place in the chamber.
2141. Chambers are equipped with protective equipment for work in electrical installations.
2142. Underground, the following are illuminated by luminaires powered from the electrical network: loaded and empty-car branches of pit bottoms; CUS, GVU pump chambers and central oil-transfer pump stations, first-aid posts, locomotive garages, waiting chambers, dispensing chambers of explosive materials stores, dispatcher chambers, tub inspection and cleaning chambers, and the approaches to such chambers where stoppings with doors are installed; points of boarding people onto trains, and the approaches to them; operating passing points and the approaches to them, and junctions of main haulage workings with other operating workings where turnouts are laid on them; pump chambers of section oil traps, section and mobile substations, and distribution points (RP) installed outside chambers; operating receiving platforms of inclines and jig inclines; and inclined workings with mechanised transport of people. The face area of development mine workings driven using roadheaders is illuminated by luminaires built into the roadheaders.
2143. A voltage not exceeding 127 V is used to supply underground lighting installations. Roadheaders, loading machines and mine locomotives are equipped with local lighting with luminaires powered at a voltage not exceeding 127 V. For hand-held portable luminaires powered from intrinsically safe sources, a voltage not exceeding 42 V may be used.
2144. Descent into an oil mine, movement of people through mine workings, and the performance of work without a switched-on cap lamp shall be prohibited.
2145. Cap lamps are sealed before use. The opening of a cap lamp in an oil mine shall not be permitted. Cap lamps and charging stations are subject to spot checks not less than once a month in accordance with the procedure established by the organisational and administrative document of the oil mine.
2146. Cap lamps are stored and serviced in premises equipped for that purpose.
2147. Cables and wires that do not propagate combustion are used in the mine workings of an oil mine for the transmission or distribution of electrical energy and information.
2148. Armoured paper-oil-insulated cables and screened cables with copper conductors insulated with cross-linked polyethylene, PVC compound or rubber are used for stationary laying. In vertical and inclined mine workings (including boreholes) with an inclination angle of more than 45°, armoured cables with wire armour or armoured cables with tape armour are used. When cables are laid in such workings, the cables are secured to a steel rope. For horizontal and inclined mine workings driven at an angle of up to and including 45°, armoured cables with tape armour may be used without securing them to a steel rope. Stationary-mounted electric motors may be connected to starting apparatus by a flexible cable, provided that the inlet devices of such motors are intended only for a flexible cable.
2149. Armoured or flexible screened cables are used for connecting mobile transformer substations, section distribution points and lighting networks.
2150. The connection of mobile electrical equipment is carried out with flexible screened cables.
2151. In the mine workings of gas-hazardous oil mines driven within the oil-bearing seam, cables with oil- and petrol-resistant insulation that does not propagate combustion are used. In other mine workings, cables are protected against the ingress of oil onto them.
2152. The use of cables of any purpose with aluminium conductors or an aluminium sheath shall not be permitted.
2153. Cables in the mine workings of an oil mine are placed on hangers intended for that purpose. When cables are laid in vertical mine workings, the distances from the cables to hoisting conveyances shall be not less than 0.3 m, and to pipelines not less than 0.5 m. When cables are laid in horizontal and inclined mine workings, the distances between the cables and pipelines made of non-combustible materials shall be not less than 0.05 m.
2154. The minimum bending radii of cables during installation and operation are determined in accordance with the manufacturer's operational documentation.
2155. For control circuits, control and signalling circuits, in stationary laying along vertical and inclined mine workings with an inclination angle of more than 45°, control fibre-optic cables, cables with copper conductors and a PVC compound sheath with wire armour, or cables with tape armour secured to a steel rope, are used. In horizontal mine workings, armoured control cables, flexible cables with copper conductors or fibre-optic cables are used. For control circuits, control and signalling circuits of mobile machines and mechanisms, flexible cables, auxiliary conductors or the optical fibres of flexible power cables are used. Signalling, control and communication cables and control cables are laid not closer than 0.2 m from power and lighting cables.
2156. For general mine and dispatcher telephone communication lines, emergency public address communication and accident notification, fibre-optic cables or cables with copper conductors, plastic insulation, a non-combustible or self-extinguishing plastic sheath and metallic armour are used. For local communication lines in mine workings being driven, flexible control cables may be used.
2157. Telephone cables and spare conductors in communication cable lines may be used for intrinsically safe control, signalling, remote monitoring and dispatching circuits.
2158. Auxiliary conductors in screened power cables may be used for control, communication, signalling and local lighting circuits. The use of auxiliary conductors of the same cable for intrinsically safe and non-intrinsically-safe circuits shall not be permitted unless such conductors are separated by screens.
2159. The laying of power cables shall not be permitted: along vertical mine workings with timber support; along inclined mine workings with a fresh air current equipped with rail transport intended for lowering and hoisting loads, except where the rail transport in such workings is used only for delivering equipment and materials and performing repair work.
2160. Individual lengths of cable may be joined by means of explosion-proof devices. Flexible cables requiring disconnection in the course of work may be connected to each other by in-line voltage connectors, provided that intrinsically safe remote control circuits with protection against short circuit in the control circuit are used. The contact pins of voltage connectors, other than intrinsically safe circuits with a voltage not exceeding 42 V, shall remain de-energised when the circuit is opened, for which purpose they are mounted on the cable on the electrical equipment side.
2161. The jointing and repair (restoration) of flexible and armoured cables in mines may be carried out using hot vulcanisation and repair kits comprising compounds and cold-shrink tubing.
2162. Cables of a single cross-section are used for feeder cable lines with a voltage of up to 1140 V carrying the total load current of consumers. Cables with conductors of different cross-sections may be used for such lines, provided that all sections of the line are protected against short-circuit currents. At points of branching from the main feeder line, where the cable conductor cross-section decreases, a device for protecting the branch against short-circuit currents is installed. Branches from the feeder line up to 20 m long may be provided, if protection against short-circuit currents is ensured by the device of the main line. The use of distribution boxes without protective devices installed on branches to electric motors is permitted only for multi-motor drives, provided that the cable of each branch is protected against short-circuit currents by a group protective device.
2163. The section of flexible cable supplying mobile machines nearest to the mobile machine may be laid along the floor for a distance of not more than 30 m. For machines fitted with a cable reel or other similar devices, the flexible cable may be laid along the floor of the mine working. Where the cable is laid in individual sections along the floor of the mine working, or temporarily placed on the floor during repair or re-support of the mine working, the cable is protected against mechanical damage by sturdy guards made of non-combustible materials.
2164. Flexible power cables and communication cables that are energised are stretched out and suspended. Keeping energised flexible cables coiled or in figure-of-eight loops shall be prohibited. This prohibition does not apply to screened cables that do not propagate combustion and are, by operating conditions, kept coiled or on drums. In such a case, the current load on the cable is reduced by 30 per cent of the rated value.
2165. When laid along boreholes cased with casing pipes, the armour of a cable with wire armour and paper insulation impregnated with non-draining compound is secured in a device that bears the cable's own weight. When a cable with tape armour and paper insulation impregnated with non-draining compound is laid, it is secured to a steel rope not less often than every 3 m, with slack between the fastening points to prevent the cable from stretching under its own weight.
2166. Cables in underground chambers are laid on hangers secured to the walls of the chambers. The laying of cables in cable channels shall not be permitted in underground chambers. In ventilation devices, ventilation stoppings, and at the inlets to and outlets from chambers, cables are laid in pipes made of non-combustible materials.
2167. The inspection of cable networks in the mine workings of oil mines is carried out in accordance with the procedure and frequency approved by the organisational and administrative document of the oil mine.
2168. In underground networks with a voltage above 1140 V, cable lines, electric motors and transformers are protected against short-circuit currents, leakage currents and earth faults. Protection against short-circuit currents, leakage currents and earth faults is provided on the feeder lines of underground substations and distribution points connected to the busbars of the main surface substation or to other surface power sources. Protection against short-circuit currents and earth leakage currents operates without a time delay. Protective trips are provided for electric motors in the event of overloads, voltage reduction or voltage loss.
2169. The selection and testing of protective devices are carried out in accordance with the procedure established by the organisational and administrative document of the oil mine.
2170. At a voltage of up to 1140 V, protection is provided for: transformers and each connection branching from them, against short-circuit currents, by circuit-breakers with maximum current protection; electric motors and the cables supplying them, branching from a section distribution point or main lines: against short-circuit currents - instantaneous or selective within up to 0.2 s; against overload; against the application of voltage at a reduced insulation resistance to earth; non-intrinsically-safe circuits with an external load, branching from the secondary windings of a step-down transformer built into the apparatus, against short-circuit currents by fuses; the electrical network against dangerous earth leakage currents, by circuit-breakers combined with a single earth leakage current relay per electrically connected network.
2171. Earth-leakage protective devices are checked for tripping before the start of each shift. Remote testing of earth-leakage protective devices may be permitted, provided that the tripping device has a pre-check insulation monitoring facility and is capable of automatically reclosing the protected line after the test.
2172. Where underground electrical networks are supplied from the surface through boreholes, a circuit-breaker with a leakage relay may be installed in the mine working at a distance of not more than 10 m from the borehole. In such a case, when the protective device trips, the surface electrical equipment and the cable in the borehole need not be disconnected, if a network insulation monitoring device is available on the surface that does not affect the operation of the protective device.
2173. Breakdown fuses are not installed on transformers located on the surface and supplying underground electrical networks equipped with earth-leakage protection.
2174. The use of fuses without cartridges and uncalibrated fuse links in protective devices shall not be permitted.
2175. Insulation resistance measurements of electrical equipment and cables are carried out before switching on: after their installation and relocation; after their emergency disconnection by protection; after their disconnection from the network for a period of more than 2 days; in the event of the tripping of an earth-leakage protective device. Insulation resistance measurement of stationary electrical equipment is carried out not less than once a year. Electrical equipment and cables whose insulation resistance does not comply with the manufacturer's operational documentation, or which causes the tripping of an earth-leakage protective device, are disconnected from the network for actions to increase their insulation resistance or for repair.
2176. The total length of cables connected to one transformer or to transformers operating in parallel is limited to a length at which the capacitance to earth per phase is not more than 1 µF.
2177. Earth-fault protection and network insulation monitoring may be omitted for circuits with a voltage not exceeding 42 V, for switchgear remote control and interlocking circuits, and for local lighting circuits of mobile substations powered from built-in lighting transformers, provided that they have a rigid or flexible metallic external connection to the substation housing, a switch is provided in the lighting circuit, and the luminaires bear the inscription "Open only after disconnection from the network".
2178. The requirement for earth-leakage protection does not apply to intrinsically safe systems.
2179. In oil mines, the following are subject to earthing: metal parts of electrical equipment not normally live but which may become live in the event of insulation damage; housings of mobile machines and apparatus installed at working faces; housings of luminaires powered from the electrical network by flexible cables; cable couplings, except connecting couplings on flexible cables supplying mobile machines; metal housings of mine communication devices, dispatcher switchboards, cable cabinets and boxes; pipelines and signal ropes located in mine workings containing electrical equipment and cable lines; pipelines, apparatus and installations of the mine oil degassing network; and equipment, apparatus, installations, pipelines and rail tracks used for the collection, primary treatment in the oil mine, transfer from tank to tank, and transportation in mobile vessels of oil, mixtures thereof with water, and petroleum products having an electrical resistivity of 105 Ω·m or higher. In gas-hazardous oil mines, single metal air ducts and fans are earthed as protection against static electricity. Metal support of mine workings and non-current-carrying rails are not subject to earthing. The construction, inspection and measurement of the resistance of mine earthing installations are carried out in accordance with the procedure established by the organisational and administrative document of the oil mine.
2180. A common earthing network is provided in the mine workings of an oil mine, to which objects subject to earthing, as well as main and local earth electrodes, are connected. This requirement does not apply to earthing devices intended for protection against manifestations of static electricity. The series connection of several earthed parts of an installation into an earthing conductor shall not be permitted.
2181. The common earthing network is created by electrically connecting together the metal sheaths and earthing conductors of cables, irrespective of the voltage in the cables. The common earthing network is connected to the main and local earth electrodes. Where an oil mine has several levels, the earthing network of each level is connected to the main earth electrodes. The armour of power cables laid between levels, or conductors laid for that purpose, is used to connect the earthing network of a level to the main earth electrode. For stationary lighting networks, local earthing may be provided every 100 m of cable network, with earthing of the last luminaire in the line. For telephone communication apparatus and cable couplings in sections of the network with unarmoured cables, local earthing without connection to the common earthing network may be permitted.
2182. The earthing of the housings of mobile machines, apparatus installed in mine workings, and luminaires connected to the network by flexible cables, is carried out by connecting them to the common earthing network by means of the earthing conductors of the cables. The earthing conductors of cables are connected at both ends to the internal earthing terminals in cable couplings and inlet devices. The electrical resistance of the earthing conductor between a mobile machine and the point of its connection to the common earthing network or local earthing shall be not more than 1 Ω.
2183. The maximum overall transient resistance of the earthing network, measured at the earth electrodes, shall be not more than 2 Ω.
2184. An oil mine is equipped with the following communication and signalling systems: a general mine and dispatcher telephone communication system; a general mine emergency notification system; signalling systems at process sections; and a system for recording official conversations. Communication and signalling systems are of intrinsically safe design, ensure electromagnetic compatibility, and are integrated into the multifunctional safety system (MFSS). In the general mine emergency notification system, in addition to public address equipment, oil mines use equipment enabling an accident message to be transmitted to the mine dispatcher from any telephone set forming part of the general mine and dispatcher telephone communication system.
2185. The operation of all types of underground communication shall be independent of the presence of voltage in the general power supply networks, whereby: communication system devices are powered from storage batteries operating only in charge-discharge mode. The powering of individual communication system devices at a voltage not exceeding 127 V from the lighting network may be permitted, provided that back-up devices powered from a storage battery are available; the powering of dispatcher communication devices with locomotive drivers and local communication devices from general electrical networks may be permitted, provided that an automatically switched-in autonomous power reserve is available. The back-up power source ensures the continuous operation of devices for not less than 3 hours.
2186. General mine and dispatcher telephone communication equipment and general mine emergency notification system equipment are installed at a height of not less than 1.5 m above the floor of mine workings.
2187. Telephone sets of the mine-wide and dispatcher telephone communication system are installed: in mine workings - at shafts, in the chambers of the main ventilation plant and central underground substations, in medical posts, in explosive materials stores, in electric machine chambers, in switchgear rated above 1140 V, at the main points of underground transport, in areas where work is carried out, in mine workings of prepared horizons and areas; on the surface - in the office premises of the areas and services of the oil mine, in production premises, in the headframe buildings of shafts, in the buildings of the main step-down substation and fan buildings; in other locations in mine workings and on the surface of the oil mine, determined by the technical manager of the oil mine in accordance with the action plan. Telephone sets in fan buildings are installed in a sound-insulated cabin with the call receiver taken outside it. No more than one telephone set may be installed on one line of an automatic telephone exchange system. Underground areas of the oil mine may be serviced by means of an automatic telephone exchange without duty telephone operators, provided that round-the-clock duty of the mine dispatcher is ensured at the mine. Plates bearing the numbers of subscribers necessary for the given facility, indicating its own number and the number for reporting an emergency, are displayed at the places where telephone sets are installed.
2188. The mine-wide emergency notification system shall ensure: transmission of an emergency signal to workers located at any point of the oil mine in emergency modes; reception on the surface of the oil mine of an emergency message transmitted from the mine; determination of the location of workers in non-emergency modes; detection and determination of the location of persons caught by an emergency in the mine; conducting negotiations and recording, with automatic recording on a data carrier, of instructions related to the elimination of the emergency.
2189. Equipment of the mine-wide emergency notification system is installed: on the surface - at the mine dispatcher of the oil mine and at the technical manager of the oil mine; in mine workings - at subscribers of the mine-wide and dispatcher telephone communication system determined by the technical manager of the oil mine.
2190. Mine-wide emergency notification systems and mine radio communication systems shall ensure electromagnetic compatibility with signalling systems.
2191. Terminal and distribution devices of communication and signalling are brought to the surface of the oil mine for maintenance and repair in accordance with a schedule approved by the technical manager of the oil mine.
2192. Communication with the mine workings of the oil mine is organised using not fewer than 2 cables laid in different shafts (boreholes) or in different compartments of one shaft and interconnected in telephone cabinets or boxes located in the workings of the pit bottom or in mine workings. Trunk and distribution telephone cables in the oil mine shall have a permanent 10 per cent reserve of spare pairs.
2193. Underground telephone lines in oil mines are two-wire. The use of earth as one of the conductors shall not be permitted. Cable pairs allocated for the mine-wide and dispatcher telephone communication system may be used only for emergency communication and notification.
2194. Parameters of systems for other purposes shall not have an interfering effect on telephone communication systems.
2195. Underground lines of the mine-wide and dispatcher telephone communication system are galvanically isolated from surface communication lines and power networks.
2196. Connection of telephone cable cores by cold twisting with insulation using polyethylene sleeves and polyethylene or polyvinyl chloride tape may be used. Before distribution devices are installed, insulation testing is carried out between terminals and between terminals and the housing.
2197. The insulation resistance of a telephone line with distribution devices shall be not less than 100 kOhm, and that of a subscriber line with distribution devices and a telephone set - not less than 50 kOhm.
2198. The signalling device of each hoisting machine shall have separate wiring and be powered from a separate power source. Except for shaft signalling, power to signalling devices may be supplied from the lighting network.
2199. The hoisting plant is equipped with a device for signalling from the shaft attendant to the underground shaft attendant and from the underground shaft attendant to the hoisting machine operator, as well as with repair signalling used during inspection and repair of the shaft, hoisting vessels and elements of the headframe. In shafts more than 500 metres deep, wireless communication means are used for repair signalling.
2200. On man-riding and man-and-material vertical and inclined hoisting plants (with an angle of inclination of the mine working exceeding 50°), in addition to operational and repair signalling, backup signalling with separate power supply via a separate cable is provided. In terms of functional capability, the backup signalling shall not differ from the operational signalling.
2201. When people are hoisted from the oil mine by skips, transmission of signals is ensured from the loading landing to the upper receiving landing and from the upper receiving landing to the hoisting machine operator.
2202. A hoisting plant serving several horizons is equipped with a device indicating from which horizon the signal was given, and a device preventing the simultaneous receipt of signals from different horizons.
2203. On man-and-material single-rope hoisting plants equipped with signalling from the cage, signalling from the receiving landings is provided, together with a device preventing the simultaneous transmission of signals from the cage and from the receiving landings. Repair signalling may be omitted on such hoisting plants. On single-cage man-riding hoisting plants equipped with signalling from the cage, signals are transmitted from the cage to the hoisting machine operator by trained workers.
2204. In inclined mine workings with an angle of inclination of up to 50°, equipped with man-riding hoists with passenger cars, signalling is provided to enable signals to be transmitted to the hoisting machine operator from the train. This signalling may be used during inspection and repair of mine workings and the rail track. In trains for transporting people consisting of more than three cars, signalling from the passenger cars to the train conductor is provided. All receiving landings are provided with telephone or industrial loudspeaker communication with the hoisting machine operator.
2205. In the shaft signalling circuit of all hoisting plants, the ability to transmit a "Stop" signal from any horizon directly to the hoisting machine operator is provided. Signboards indicating the signals used are displayed at all places of signal reception and transmission. On receipt of an unclear or non-standard signal, the hoisting plant is stopped.
2206. Transmission of a signal from the pit bottom directly to the hoisting machine operator, bypassing the shaft attendant located at the ground-level landing of the shaft, shall not be permitted. This prohibition does not apply to: signalling devices with an interlock preventing the machine from starting before a permitting signal is received from the shaft attendant in the pit bottom; single-cage hoisting plants with signal transmission from the cage; repair signalling. A signal for hoisting operation may be given only after the cage door and shaft gates have been closed.
2207. Direct telephone or two-way loudspeaker communication is provided between the hoisting machine operator and the shaft attendant in the pit bottom, and between the shaft attendant in the pit bottom and the shaft attendant at the ground-level landing of the shaft.
2208. Cages intended for hoisting and lowering people are equipped with means of communication with the engine room, used during maintenance of the cages and repair of the shaft.
2209. Measures for the safe conduct of mining operations and oil production operations in mine workings where inrushes of water are possible are included in the design documentation, the documentation for the conduct of mining operations and the documentation for the conduct of oil production operations.
2210. Before work begins in mine workings where inrushes of water are possible, the areas hazardous for water inrush are identified.
2211. Flooded or silted mine workings in which water or liquid clay is found are classified as areas hazardous for water inrush.
2212. Mining operations in areas hazardous for water inrush are carried out in compliance with measures to prevent the inrush of water into mine workings.
2213. When mining operations are carried out within the zone of influence of wells drilled from the surface, measures are provided to eliminate the possibility of surface water inrush into mine workings.
2214. Caving zones, open cracks and ground surface subsidence formed during mining operations are enclosed by drainage channels providing for the diversion of flood and storm water.
2215. On detecting signs of a possible water inrush into a mine working, all persons in that working shall stop work, leave that mine working and report the signs of a possible water inrush to the mine dispatcher of the oil mine.
2216. Work on pumping out and/or draining water from flooded mine workings is carried out in compliance with measures ensuring industrial safety and the safe conduct of that work.
2217. Measures for the safe conduct of mining operations and oil production operations in mine workings where breakthroughs of heat-transfer fluid are possible are included in the design documentation, the documentation for the conduct of mining operations and the documentation for the conduct of oil production operations.
2218. Before work begins in mine workings where breakthroughs of heat-transfer fluid are possible, the areas where breakthroughs of heat-transfer fluid are possible are identified.
2219. Areas of mine workings where breakthroughs of heat-transfer fluid are possible are fenced off and marked with warning signs.
2220. Locations where heat-transfer fluid injection or oil production work is carried out in mine workings are inspected every shift by workers of the structural subdivision to which those workings are assigned.
2221. At all times not occupied with work on wells, workers shall remain in the locations specified in the shift assignment outside the areas of the mine working where breakthroughs of heat-transfer fluid are possible, on the side where the fresh air stream enters that working.
2222. Workers performing work in areas of mine workings where breakthroughs of heat-transfer fluid are possible shall be trained in first aid for burns, shall know the locations of rescue equipment and shall be able to use it.
2223. On detecting signs of a possible breakthrough of heat-transfer fluid into a mine working, all persons in that working shall stop work, leave that mine working and report the signs of a possible breakthrough of heat-transfer fluid to the mine dispatcher of the oil mine.
2224. After breakthroughs of heat-transfer fluid and their consequences have been eliminated in a mine working, work in that working is resumed with the written permission of the technical manager of the oil mine.
2225. Resumption of heat-transfer fluid injection work in a mine working after the elimination of breakthroughs of heat-transfer fluid is carried out in the absence of people in that working.
1. In column 19, distances indicated as a fraction: the numerator - to open transformer substations and switchgear, the denominator - to enclosed transformer substations and switchgear.
2. hfkl - height of the flare stack.
1. The Emergency Response Action Plan (PMLA) for a hazardous production facility of an oil mine is developed by the organisation operating the hazardous production facility, or by its separate structural subdivision, for each hazardous production facility or its fire- and explosion-hazardous area, workshop or other subdivision.
2. The PMLA shall provide for: 2.1. Possible emergencies, the locations of their occurrence and conditions hazardous to human life. 2.2. Actions for rescuing people caught by an emergency. 2.3. Actions for eliminating emergencies at the initial stage of their occurrence, as well as the priority actions of workers when emergencies occur. 2.4. The locations of equipment for rescuing people and eliminating emergencies. 2.5. The procedure for interaction with the professional emergency rescue service (PASF). 2.6. For the PMLA of facilities of fields with a high hydrogen sulphide content in the product, safe locations and an evacuation procedure taking into account specific weather conditions shall be established.
3. PMLAs are developed by a commission consisting of workers appointed by order of the enterprise. PMLAs are revised within the time limits established by the Government of the Russian Federation. When technology, working conditions or safety rules change, corresponding amendments and additions shall be made to the PMLA.
4. The PMLA, in five copies, is approved by the technical manager of the enterprise provided that inspection reports are available on: the condition of process control systems; the condition of ventilation devices; the availability and serviceability of equipment for rescuing people, fire-fighting equipment and technical means for eliminating emergencies at their initial stage; the serviceability of emergency signalling, communication and emergency lighting.
5. The PMLA shall contain: 5.1. An operational section providing for all types of possible emergencies at the given facility, identifying the actions for rescuing people and eliminating the emergency, as well as the persons responsible for carrying out the actions and the persons performing them, the locations of equipment for rescuing people and eliminating emergencies, and the actions of gas rescuers, firefighters and other units. 5.2. The allocation of responsibilities among the individual persons involved in eliminating the emergency. 5.3. A list of officials and institutions to be notified of the emergency immediately. 5.4. Layout diagrams of the main utilities (process flow diagram) of the blowout preventer (BOP) manifold, wellhead equipment, process equipment and vehicle traffic routes at the hazardous production facility. 5.5. Lists of tools, personal protective equipment and materials required for eliminating emergencies and kept in emergency cabinets (rooms), indicating their quantity and principal characteristics.
6. The operational section of the PMLA shall provide for: 6.1. Methods of notifying of an emergency (for example, siren, light signalling, loudspeaker communication, telephone) and routes for people to leave hazardous locations and areas depending on the nature of the emergency. 6.2. The actions of workers responsible for evacuating people and carrying out the prescribed actions. 6.3. The ventilation operating mode in the event of an emergency, including the switching-on of emergency ventilation (where provided). 6.4. The necessity and sequence of switching off electric power, stopping equipment and apparatus, and shutting off sources of harmful and hazardous substances. 6.5. The posting of checkpoints on approach (access) routes to hazardous locations to control access to gas-contaminated and hazardous zones. 6.6. Methods of eliminating emergencies at the initial stage. The priority actions of workers for eliminating emergencies, preventing an increase in their scale and complications. The implementation of actions to prevent severe consequences of emergencies. The procedure for interaction with the PASF.
7. Workers' familiarisation with the PMLA shall be recorded in documentary form against signature.
8. Complete copies of the PMLA shall be kept in the dispatcher's office of the enterprise, with the gas rescuers, the PASF and the industrial safety service of the enterprise, and with the head of the structural subdivision (workshop). The operational section of the PMLA shall be displayed at the workplace determined by the head of the facility (area).
9. Responsibility for the timely and correct drawing-up of the PMLA and its conformity with the actual situation at the production facility rests with the head of the facility and the technical manager of the enterprise.
10. The frequency of training exercises for developing skills in carrying out the actions of the PMLA, except in cases established by these Rules, is determined by the organisation taking into account specific conditions, but not less than once a year.
11. The results of training exercises under the emergency response action plan shall be entered in the logbooks for registering training exercises under the PMLA, against the signature of the workers taking part in the exercise.
1. The general description of the production facility includes: the full name of the hazardous production facility, its purpose and the year it was commissioned; the names of the research and design organisations that developed the process and carried out the design; the number of process lines (streams) and their purpose.
2. The description of the feedstock, materials, reagents and manufactured products includes: the technical name of the products, quality in accordance with regulatory technical documentation, and the field of application; the explosion and fire hazard properties and toxicity of the feedstock, reagents, finished products and production waste are given in paragraph 7 of this Appendix.
3. The description of the process and the process flow diagram of the production facility includes: a description of the process in strict conformity with the process flow diagram, which is a graphic appendix to the process regulations (TR); the description of the process flow diagram is given by stages of the process, starting from the receipt of feedstock, indicating the principal process parameters (temperature, pressure, throughput) of the equipment involved in the process and included in the process flow diagram. The main automation and interlock schemes are indicated in the course of describing the diagram.
4. Process regime standards for continuous and batch processes are given in accordance with Table No. 1 of this Appendix.
In the column of Table No. 1 of this Appendix headed "Name of process stages, apparatus, regime indicators", the regulated regime indicators at various stages of the process in apparatus (settling tanks, electric dehydrators, columns, furnaces, reactors, heat-exchange and other apparatus) are indicated: temperature, pressure, flow rate, duration of operations, quantity of components charged or fed, and other indicators affecting safe operation and product quality;
when marking instrumentation and control (I&C) devices on control panels, the position numbers of the devices shall correspond to the position numbers on the process flow diagram;
units of measurement are given in the SI system currently in force.
All regime indicators, including flow rate, pressure and temperature, are indicated with possible tolerances or ranges ensuring safe operation and the production of finished products of the specified quality. Limitation of upper or lower limit values is permitted. For example: "vacuum, not less than...", "temperature, not more than...".
5. Process control includes: analytical control (laboratory, automatic) at all stages of the process, set out in accordance with Table No. 2 of this Appendix.
At the beginning of the table, laboratory control standards are indicated, followed by automatic control standards:
if the products being monitored contain aggressive components causing metal corrosion, the permissible content of these components and the methods for monitoring them are indicated;
control of the process by means of signalling and interlock systems, where such exist, is given in the form of a list in accordance with Table No. 3 of this Appendix.
6. The principal provisions for starting up and shutting down the production facility under normal conditions include: interconnection with other process and auxiliary facilities, and the supply of the unit with feedstock, electric power, steam, water, air and other materials and resources; the specific features of start-up and shutdown in winter; a description of the start-up and shutdown of fire- and explosion-hazardous production facilities; the sequence of start-up and shutdown, and compliance with the required operating regime, indicating the consequences of its violation.
7. Safe operation of the production facility includes: data on the existing production hazards which may lead to explosion or poisoning, and a set of technical, process and organisational actions ensuring a minimum level of production hazard; the explosion and fire hazard properties and toxic properties of the substances used and produced, given in accordance with Table No. 4 of this Appendix.
Where necessary, as established by the operating organisation, the classification of process blocks by explosion hazard is carried out in accordance with the requirements of the Federal Norms and Rules establishing the general explosion safety rules for fire- and explosion-hazardous chemical, petrochemical and oil-refining production facilities, and is given in accordance with Table No. 5 of this Appendix.
For process systems, the categories of electric power receivers and the reliability of power supply are indicated, as well as the power supply arrangements for control, management and emergency protection systems;
8. Methods and means of protecting workers from production hazards include: methods and means of monitoring the content of explosive and toxic substances in the air of the working area; the frequency and methods of monitoring the formation of explosive concentrations during the operation of the production facility.
9. Additional safety measures for the operation of production facilities include: safe methods for handling pyrophoric deposits; methods for neutralising and decontaminating production products in the event of spills and emergencies; personal and collective protective equipment for workers and for extinguishing possible fires; the possibility of the build-up of static electricity charges, their hazard and methods of neutralisation; a safe method for removing production products from process systems and individual items of equipment; the principal hazards of the equipment and pipelines used and their critical components, and actions for preventing an emergency loss of integrity of process systems.
10. The brief description of process equipment, control valves and safety valves includes a description of all the equipment shown in the graphic appendix of the process flow diagram to the process regulations (TR). The brief description of process equipment is drawn up in accordance with Table No. 6 of this Appendix.
The name of the equipment is indicated in accordance with the equipment's technical data sheet (log).
The brief description of control valves is given in accordance with Table No. 7 of this Appendix.
The brief description of safety valves (where such exist) is given in accordance with Table No. 8 of this Appendix.
11. The list of mandatory instructions and regulatory technical documentation includes process instructions, job descriptions and labour protection instructions required for ensuring the safety of the process and the maintenance and repair of equipment. This list also gives the regulatory technical documentation approved by the organisation's management, as well as the standard instructions, standards and rules currently in force that are mandatory for guidance and compliance by the organisation's workers.
12. The process flow diagram for product manufacture is a graphic appendix to the section "Description of the process". The process flow diagram for continuous processes is drawn up for one process train (where several identical streams exist), including the principal process apparatus, the principal material lines, the principal control and regulating devices, and the points for monitoring and regulating process parameters. The symbols for control and automation devices, as well as for valves and fittings, shall be indicated on the diagram. The process flow diagram is signed by the head of the facility and approved by the chief engineer (technical manager) of the organisation.
13. The equipment schedule is given in accordance with Table No. 9 of this Appendix.
We, the undersigned, have drawn up this report on the following:
1. Well No. ___, drilled by _____________ in ____, in accordance with design No. ___ dated _______, prepared by ________________, carried on the books of _____, has been abandoned ________ under category ______ in accordance with Chapter LVIII of the Federal Norms and Rules "Safety Rules in the Oil and Gas Industry"
2. The well bottom is at ___ m.
3. Cement plugs have been set in the well at depths of ___ m.
4. Installed at the wellhead are ___________________ and a marker post bearing the inscription ___________________________________________________________________________ ___________________________________________________________________________
5. The following equipment has been dismantled and removed from the well: - christmas tree and casing head __________________ - tubing __________________ in the quantity of _________________ t - downhole equipment package ________________ - casing pipe ___________ in the quantity of ____________ t. - casing pipe ___________ in the quantity of ____________ t.
6. All materials on the abandoned well No. __________ have been bound, certified with a seal and signatures, and transferred for safekeeping to _________________. Authorised representative of the territorial office of Rostechnadzor Authorised representative of the subsurface user organisation
1. In double-track sections of mine workings of all pit bottoms, in single-track pit-bottom mine workings of cage shafts, and in all other places of double-track mine workings where shunting operations, coupling and uncoupling of cars or trains (at passing points) and transfer of equipment and materials from one vehicle to another are carried out, at stationary loading points with a capacity of 1000 t per day or more, and at transit loading points in the absence of a bypass mine working regardless of capacity, passages for people are provided at 0.7 m on both sides.
2. The width of passages for people and clearances shall be maintained over the height of the mine working at not less than 1.8 m from the floor. Passages are provided on one side along the entire length of the mine working. In double-track mine workings, the arrangement of passages between the tracks shall not be permitted.
<*> Average concentration across the cross-section of the ventilation air stream.
1. Testing of mine air composition is carried out by workers of the professional emergency rescue service (PASF) units servicing the oil mine and/or by workers of gas-analysis laboratories in the presence of a worker of the aerological safety service once a quarter. The locations in mine workings where mine air composition testing needs to be carried out are determined by a worker of the aerological safety service. Testing of mine air composition (sampling) is carried out by a worker of the PASF and/or of the gas-analysis laboratory.
2. The procedure for testing mine air composition by workers of the aerological safety service is determined by the technical manager of the oil mine.
3. In oil mines, mine air composition testing is carried out for the content of carbon dioxide, hydrocarbon gases and liquid hydrocarbon vapours, hydrogen sulphide and oxygen. Testing of mine air composition from charging chambers is carried out for the content of carbon dioxide, hydrocarbon gases and liquid hydrocarbon vapours, hydrogen sulphide, oxygen and hydrogen. Testing of mine air composition from mine fire areas is carried out for the content of carbon monoxide, carbon dioxide, hydrocarbon gases and liquid hydrocarbon vapours, hydrogen sulphide and oxygen. Testing of mine air composition after blasting operations is carried out for the content of carbon monoxide, nitrogen oxides, hydrogen sulphide, sulphur dioxide, carbon dioxide, hydrocarbon gases and liquid hydrocarbon vapours, and oxygen. When analysing hydrocarbon gases and liquid hydrocarbon vapours, the content of methane, ethane, propane, isobutane, butane, isopentane, pentane and liquid hydrocarbon vapours is determined. Where the temperature of mine air in mine workings exceeds 20°C, measurements of relative humidity are carried out. Where mine air is conditioned, temperature and relative humidity are determined at workplaces and at cooling points.
4. Testing of mine air composition and measurement of its flow rate are carried out: at oil mines not hazardous by gas - once a month; at oil mines hazardous by gas - three times a month;
5. The output of the auxiliary fan (VMP) is measured once a month.
6. Testing of mine air composition after blasting operations is carried out once a month: in shafts, regardless of their depth; in development workings where their length is 300 m or more; when the drilling-and-blasting specification is changed. During the sinking of shafts transferred to gas mode, testing of mine air composition is carried out three times a month.
7. Samples taken for testing mine air composition shall characterise the average gas concentrations across the cross-sections of ventilation air streams. Testing of mine air composition is carried out during shifts when working development, well drilling and oil production operations are being carried out in the workings. Testing is carried out not earlier than one day after a non-working day.
8. The time for starting the sampling of mine air after blasting operations is determined by the head of the aerological safety service. The first samples are taken not earlier than 15 minutes after conventional blasting and not earlier than 30 minutes after shock blasting. Subsequent samples are taken at intervals of not more than 5 minutes for 10-15 minutes after the first samples are taken.
9. When testing mine air composition, the total content of hydrocarbon gases and liquid hydrocarbon vapours, and the content of carbon dioxide, carbon monoxide, oxygen, hydrogen, nitrogen oxides, sulphur dioxide and hydrogen sulphide are determined with the following accuracy: hydrocarbon gases and liquid hydrocarbon vapours, carbon dioxide, oxygen and hydrogen - not more than +/- 0.1 volume fraction, per cent; carbon monoxide (at a content of up to 2 maximum permissible concentrations (hereinafter - MPC)) - not more than +/- 0.0005 volume fraction, per cent; carbon monoxide (at a content of more than 2 MPC) - not more than +/- 10 per cent of the measured value; nitrogen oxides, sulphur dioxide and hydrogen sulphide - not more than +/- 25 per cent of the measured value. When carrying out laboratory studies of mine air composition, equipment ensuring determination of 0.5 MPC is used.
10. Measurements of carbon dioxide content and total content of hydrocarbon gases and liquid hydrocarbon vapours in oil mines hazardous by gas are carried out using stationary sensors of the automatic gas control (AGK) system and portable monitoring devices. Measurements of carbon dioxide content and total content of hydrocarbon gases and liquid hydrocarbon vapours in oil mines not hazardous by gas are carried out using portable monitoring devices.
11. Testing of the composition of mine air and measurement of its flow rate are carried out: in the main intake air currents of the mine; in the intake air currents of the wing, panel, block and level; in the intake and return air currents of preparatory workings and workings where well drilling or oil extraction is carried out; in the return air currents of the wing, panel, block, level and the mine as a whole; at auxiliary fans; at the faces of preparatory workings; in charging chambers; at locations where hydrocarbon gases and liquid hydrocarbon vapours are released into mine workings with a fresh air current; at the faces of dead-end rising workings; at locations established by the technical manager of the oil mine.
12. The plan for testing the composition of mine air is drawn up for a quarter and is approved by the technical manager of the oil mine. The retention period for the mine air testing plan is 1 year.
13. No later than the 25th day of the last month of the current quarter, the plan for testing the composition of mine air is sent to the unit of the professional emergency rescue service (PASF) servicing the oil mine and (or) to the gas analysis laboratory. The PASF unit and (or) the gas analysis laboratory draws up, for each month, a schedule for testing the composition of mine air, which is sent to the oil mine no later than three days before the start of the next month.
14. On the days provided for in the schedule for testing the composition of mine air, the PASF and (or) gas analysis laboratory employee carrying out the test obtains, at the laboratory, a mine air test record-order. The mine air test record-order is signed by the head of the aerological safety service. The head of the aerological safety service enters into the record-order any amendments and (or) additions in accordance with the actual state of the mining operations. Each amendment and (or) addition is confirmed by the signature of the head of the aerological safety service. In the mine air test record-order made after blasting operations, the head of the aerological safety service indicates, in the "Note" column, the time at which the first samples were taken after the blasting operations.
15. Mine air samples are sent to the unit of the professional emergency rescue service (PASF) servicing the oil mine and (or) to the gas analysis laboratory. Notice of the results of the mine air sample analysis is sent to the technical manager of the oil mine no later than 24 hours from the time the samples are received. Where the results of the mine air sample analyses reveal concentrations of the monitored gases exceeding the maximum permissible concentrations, they are passed to the mine dispatcher (duty dispatcher) of the oil mine, and information on the exceedances of the monitored gas concentrations is sent to the territorial authority of the Federal Environmental, Industrial and Nuclear Supervision Service (Rostechnadzor).
16. Where the concentration of harmful gases exceeds the permissible limits, testing of the composition of mine air in mine workings is carried out by PASF employees wearing respirators.
17. The results of testing the composition of mine air and its flow rate are entered in the ventilation log, the structure and form of which are determined by the technical manager of the oil mine.
18. The decision to have the composition of mine air tested by employees of the aerological safety service is taken by the technical manager of the oil mine. Mine air samples taken by employees of the aerological safety service are passed to the gas analysis laboratory. The samples are accompanied by a mine air test record-order signed by the head of the aerological safety service. The mine air test record-order indicates the gases for which analysis is required and the gas concentrations measured with portable monitoring instruments at the time the sample was taken.
19. Testing of the composition of mine air is carried out: in workings where well drilling or oil extraction is conducted, not further than 15-20 m from the point where the ventilation air current enters the working; in workings where well drilling or oil extraction is conducted, not further than 15-20 m from the point where the ventilation air current leaves the working; in workings with an air current issuing from a preparatory working, not further than 15-20 m from the point where the ventilation air current leaves; at 15-20 m from points where ventilation air currents merge or split; in preparatory workings not more than 20 m from the portal and at the face, including during shaft sinking; in preparatory workings, after blasting operations, at 20-30 m from the portal (in the upper part of the working cross-section); in charging chambers, in the upper part of the chamber cross-section on the return-current side.
20. The procedure for monitoring the concentration of sulphur dioxide and hydrogen sulphide is established by the technical manager of the oil mine.
21. When testing the composition of mine air, samples are taken into gas-tight containers. Mine air samples taken are analysed in the gas analysis laboratory no later than 12 hours after they are taken.
22. Sampling for heavy hydrocarbons is carried out by the "wet" method into gas-tight containers with a capacity of 0.5 l.
23. When taking samples into vessels (burettes) by the flow-through method, a volume of mine air exceeding the capacity of the vessel by at least ten times is passed through the vessel.
24. The concentration of harmful gases is monitored using portable monitoring instruments.
25. Sampling of mine air averaged over the cross-section of the working is carried out in the following order: the employee takes samples holding the vessel (container) in front of him at arm's length, facing the air current; the vessel (container) is filled with mine air while being moved in the horizontal and vertical directions. Filling starts at the floor and finishes at the roof of the working. The employee ensures that the vessel (container) is filled uniformly across the cross-section of the working.
26. In vertical workings, the vessel (container) is moved in the horizontal plane when taking a mine air sample.
27. Mine air samples from behind stoppings, from boreholes and from inaccessible locations are taken remotely through tubes.
28. Before taking samples from behind an isolation stopping or from a borehole, the temperature of the mine air at the isolation stopping, behind the isolation stopping (in the borehole), and the atmospheric pressure at the sampling point are measured. Mine air samples are not taken from behind an isolation stopping or from a borehole where mine air is flowing from the working into the space behind the isolation stopping (into the borehole). Where mine air is flowing from the working into the space behind the isolation stopping (into the borehole), the following entry is made in the mine air test record-order: "the stopping (borehole) is receiving".
29. Measurements of mine air velocity are carried out in straight sections of mine workings, not less than 15 m long, with supports fitting closely against the walls of the working. Within a section of not less than 15 m from the measurement point, objects, materials and mining equipment reducing the cross-sectional area of the working shall not be permitted in the working. The measurement point is selected at a distance of not less than 15 m from (to) the junction of the working in which the mine air velocity is measured with other workings.
30. Diagrams of the movement of the measuring instrument across the cross-section of the mine working when measuring mine air velocity are given in Figure 1 of this Appendix. Fig. 1. Diagrams of the movement of the instrument across the cross-section of the mine working when measuring mine air velocity. Measurements of mine air velocity are carried out by the following methods: the employee carrying out the measurement is located in the same cross-section of the mine working in which the velocity is measured - the "in-section" method; the employee carrying out the measurement is located at arm's length from the cross-section in which the velocity is measured - the "in-front" method; the employee carrying out the measurement is located at a distance of 1.5-2 m from the cross-section in which the velocity is measured. To carry out measurements by this method, the measuring instrument is attached to an extension rod, for which purpose either special devices or various objects of the specified length may be used.
31. The "in-front" method of measuring mine air velocity is used where the height of the working does not exceed 2 m. The average mine air velocity in the working is determined taking into account correction coefficients K, depending on the measurement method used: for the "in-front" method, the coefficient is 1.14; for the "in-section" method, the coefficient is determined from the expression K = (S - 0.4) / S, where S is the clear cross-sectional area of the working, m2. Where the velocity is measured with the measuring instrument located at a distance of not less than 1.5 m from the employee, no correction coefficient is applied.
32. The minimum duration of a measurement is determined by the time taken for a single movement of the measuring instrument across the cross-section of the mine working along one of the diagrams given in this Appendix. Where the measurement time is increased, the measuring instrument is moved across the cross-section of the working along a single diagram. The measurement of mine air velocity is considered complete where the measuring instrument has been moved along the adopted diagram across the cross-section of the working one or more times and is located at the point where the measurement began. Measurements of mine air velocity are carried out not less than 3 times. The average mine air velocity in the working is taken from 3 measurements.
33. The cross-sectional areas of mine workings S, m2, shown in Figure 2 of this Appendix, are determined as follows: Fig. 2. Cross-sections of mine workings: (a) trapezoidal cross-section; (b) box-vault; (c) semicircular vault; (d), (e) arch-shaped cross-section; (f) trapezoidal cross-section of complex shape: S = 0.5H(a + b), where H is the height of the working (clear), m; a is the width of the working at the roof (clear) or at the level at which the arch of the working support forms, m; b is the width of the working at the floor (clear), m; box-vault: S = ah + 0.78a(H - h), where h is the height of the working (clear) at the level at which the arch of the working support forms, m; for a semicircular vault: , for an arch-shaped cross-section: ,
34. To determine the cross-sectional area of a working of complex shape, the method of dividing the cross-section into elementary figures of regular shape is used.
35. The mine air flow rate in the cross-section of a mine working, Q, m3/min, is determined by the formula: Q = 60vS, where v is the average velocity of mine air movement in the working, m/s.
36. To determine the output of an auxiliary fan, measurements of mine air flow rate are carried out in the working in which it is installed, at 5-10 m in front of the fan and at 5-10 m behind it, counting in the direction of movement of the air current. The output of the auxiliary fan is determined as the difference between the average values of mine air flow rate at the first and second measurement points. Where the distance from the auxiliary fan installation point to the portal of the preparatory working is less than 50 m, and it is not possible, in this section of the working in which the auxiliary fan is installed, to measure the mine air flow rate, the output of the auxiliary fan is taken as equal to the mine air flow rate measured in the preparatory working at a distance of not more than 10 m from its portal.
37. Measurements of the mine air flow rate entering the face of a preparatory working ventilated by an auxiliary fan are carried out at 15-20 m from the face in the cross-section of the working. Where it is not possible to measure the mine air velocity in the cross-section of the working, the mine air flow rate entering the face is determined from the mine air flow rate in the ventilation duct at the point where the ventilation air current leaves the duct into the ventilated working.
38. When measuring the temperature and relative humidity of mine air, measuring instruments are positioned as follows: in shafts - at a distance from the shaft wall. Measurements are carried out at not less than two points spaced from each other around the circumference of the shaft; in inclined and horizontal workings - at a distance from the wall equal to 0.3 of the width of the working, and at a height from the floor equal to 0.4 of the height of the working. Measurements are carried out at two points on each side of the working; in workings after the merging of ventilation air currents, temperature is measured at three points located at an equal distance from each other and from the side walls, equal to 0.25 of the width of the working, and at a height from the floor equal to 0.4 of the height of the working; in the face areas of preparatory workings, temperature is measured at a distance of up to 5 m from the end of the ventilation duct towards the portal, at three points located at an equal distance from each other and from the side walls, equal to 0.25 of the width of the working, and at a height from the floor equal to 0.4 of the height of the working. The value of the mine air temperature in the cross-section of the working is determined as the average value of all measurements.
39. The procedure for measuring temperature and relative humidity when conditioning mine air is determined by the technical manager of the oil mine.
40. The results of temperature, humidity and air velocity measurements are recorded in the ventilation log, drawn up in the form established by the organisational and administrative document of the oil mine.
41. Portable individual monitoring instruments for these gases shall be used to monitor the total concentrations of hydrocarbon gases and liquid hydrocarbon vapours, and the concentrations of carbon monoxide, carbon dioxide and oxygen in mine air. The procedure for using portable individual instruments of periodic or continuous operation is determined by the technical manager of the oil mine.
42. In oil mines not hazardous by gas, monitoring of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours, and of the concentrations of carbon monoxide, carbon dioxide and oxygen, by group or individual monitoring instruments is carried out: in the face areas of preparatory workings; in the return air currents of workings in which well drilling or oil extraction operations are conducted; at cutting machines, in cases where the cutting machines are not equipped with built-in automatic instruments for monitoring the total concentration of hydrocarbon gases and liquid hydrocarbon vapours; in dead-end sections of ventilation workings being abandoned. In oil mines hazardous by gas, monitoring of the concentration of hydrocarbon gases and liquid hydrocarbon vapours, carbon monoxide, carbon dioxide and oxygen is carried out by individual or group instruments: in the face areas of preparatory workings; at places where people work in workings with a return current of mine air; at cutting machines, in cases where the cutting machines are not equipped with built-in automatic instruments for monitoring the total concentration, automatic instruments for monitoring the total concentration of hydrocarbon gases and liquid hydrocarbon vapours; on electric locomotives; at drilling rigs; in dead-end sections of ventilation workings being abandoned. Group instruments for monitoring the total concentration of hydrocarbon gases and liquid hydrocarbon vapours, and the concentration of carbon monoxide, carbon dioxide and oxygen, are not used at places where mining operations are conducted: where stationary equipment for monitoring the total concentration of hydrocarbon gases and liquid hydrocarbon vapours, and the concentration of carbon monoxide, carbon dioxide and oxygen, is present; where all workers performing these operations have individual monitoring instruments. In workings with a return current of mine air and on battery electric locomotives, monitoring of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours by group instruments is not carried out where workers have individual instruments for monitoring the total concentration of hydrocarbon gases and liquid hydrocarbon vapours.
43. Group instruments for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours are placed: in preparatory workings - at 3-5 m from the face, on the side of the working opposite the ventilation duct; in workings with an air current issuing from a working in which well drilling or oil extraction operations are conducted - at places where people work; at drilling rigs - at a distance of not more than 1 m from the well being drilled, in the direction of movement of the ventilation air current. Monitoring of the total content of hydrocarbon gases and liquid hydrocarbon vapours by group instruments is carried out at the locations where it is at its maximum. Group monitoring instruments are installed as follows: where only methane is present - directly under the roof of the working; where heavy hydrocarbons and liquid hydrocarbon vapours are present - at the floor of the working; when monitoring carbon dioxide - in the lower part of the working; when monitoring carbon monoxide and oxygen - in the middle of the working.
44. Group monitoring instruments are suspended so that the air flow reaches them from the side opposite the front panel of the instrument.
45. The list of locations and the frequency of monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours, and the content of carbon monoxide, carbon dioxide and oxygen in mine air by individual and group instruments, is approved quarterly by the technical manager of the oil mine.
46. The frequency of monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours, and the content of carbon monoxide, carbon dioxide and oxygen in mine air by individual instruments is established as follows: for oil mines in which the total concentration of hydrocarbon gases and liquid hydrocarbon vapours is monitored by portable automatic instruments, at the faces of active dead-end workings and shafts, and in the return ventilation air currents of dead-end workings and workings in which wells are drilled and/or operated - not less than once per shift, by an employee of the aerological safety service; for oil mines in which the total concentration of hydrocarbon gases and liquid hydrocarbon vapours is monitored by stationary sensors of AGC systems, at the faces of active dead-end workings and shafts, and in the return ventilation air currents of dead-end workings and workings in which wells are drilled and/or operated - not less than 2 times per shift by well workers - not less than 2 times per shift by workers of technological sections. One of the measurements is carried out at the start of the shift. Monitoring is carried out not less than once per day by an employee of the aerological safety service; in the ventilation air currents entering active dead-end and production workings, in dead-end and production workings where no operations are conducted and in their return currents, in mine workings where no gas release has been observed, in the return currents of the wing, panel, block, level and mine, and in other workings, the condition of mine air is monitored by an employee of the technological section and an employee of the aerological safety service not less than once per day; in machine chambers, measurements of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours are carried out not less than once per shift by shift workers of the sections or by employees servicing the chambers, and not less than once per day by employees of the aerological safety service; for oil mines hazardous by gas, in workings where local accumulations of hydrocarbon gases and liquid hydrocarbon vapours may form, and also in sections of workings hazardous by layer accumulations, measurements of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours are carried out by employees of the structural subdivisions of the sections not less than 3 times per shift, and by employees of the aerological safety service not less than once per day; for oil mines not hazardous by gas, at the faces of active dead-end workings and shafts, and in the return ventilation air currents of dead-end workings and workings in which wells are drilled and/or operated, where there are no stationary sensors of AGC systems in these workings - not less than 3 times per shift by employees and workers of the structural subdivisions. One of the measurements is carried out at the start of the shift. Monitoring is carried out not less than once per day by an employee of the aerological safety service.
47. Monitoring by individual instruments of the total content of hydrocarbon gases and liquid hydrocarbon vapours, and the content of carbon monoxide, carbon dioxide and oxygen in mine air, is carried out at locations where stationary sensors of AGC systems are installed.
48. The employee of the structural subdivision whose duties include monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours, and the content of carbon monoxide, carbon dioxide and oxygen in mine air during a shift, is designated by the head of the structural subdivision or by a person appointed by him.
49. The results of monitoring by individual instruments obtained by employees of the technological sections and employees of the aerological safety service are entered on the notice boards showing the results of mine air composition monitoring and in the work assignment sheets, drawn up in the form established by the organisational and administrative document of the oil mine. The notice boards showing the results of mine air composition monitoring are installed in the face areas of preparatory workings, in the return currents of preparatory workings and workings in which oil wells are drilled and (or) oil extraction is conducted, in the return currents of the wing, panel, block, level and mines, and in the currents entering production sections.
50. The list of sections of workings hazardous by layer accumulations of hydrocarbon gases and liquid hydrocarbon vapours is drawn up by the head of the aerological safety service and an employee of the geological service of the oil mine. The list of sections of workings hazardous by layer accumulations of hydrocarbon gases and liquid hydrocarbon vapours indicates the locations for taking measurements of hydrocarbon gases and liquid hydrocarbon vapours for the purpose of detecting layer accumulations. The mining and geological, and mining engineering conditions under which a section of a working is classified as hazardous by layer accumulations of hydrocarbon gases and liquid hydrocarbon vapours are given in Table No. 1. Where the mining and geological, and mining engineering conditions change, the necessary corrections and additions are made, within 24 hours, to the list of sections of workings hazardous by layer accumulations of hydrocarbon gases and liquid hydrocarbon vapours.
51. Measurements of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours for the purpose of detecting their layer accumulations are carried out at the locations specified in Table No. 2. Where gas blower emissions are present in preparatory workings, concentration measurements are carried out at the locations of the gas blower emissions and at a distance of 20 m from them in the direction of movement of the air current.
52. To determine the gas emission rate of oil mines hazardous by gas, the content of carbon dioxide, methane, ethane, propane, isobutane, butane, isopentane, pentane and liquid hydrocarbon vapours is determined.
53. The gas emission rate of the mine is determined from the results of tests carried out on the composition of mine air and measurements of its flow rate.
54. To determine the gas emission rate, data from measurements by portable individual instruments and data from the AGC system are used. To determine the gas emission rate from the sum of hydrocarbon gases and liquid hydrocarbon vapours, using data obtained when monitoring the condition of the mine atmosphere by portable or stationary monitoring instruments, the total concentration of hydrocarbon gases and liquid hydrocarbon vapours, % (by volume), is determined by the formula: C = 0.01K·NCM, where K is the concentration of the mixture of hydrocarbon gases and liquid hydrocarbon vapours in mine air, % (of the LEL of the mixture); NCM is the LEL of the mixture of hydrocarbon gases and liquid hydrocarbon vapours, %. , where S1, S2 ... Sn are the content of each hydrocarbon gas or vapour in the mixture, determined by laboratory analysis, % (by volume); N1, N2 ... Nn are the LEL of each hydrocarbon gas or vapour, %.
55. The flow rate of the mixture of hydrocarbon gases and liquid hydrocarbon vapours (hereinafter referred to simply as the "mixture", meaning by this term both the mixture of hydrocarbon gases and liquid hydrocarbon vapours and pure methane or carbon dioxide), passing at the measurement point at each measurement, m3/min, is determined by the formula: I = 0.01QC, where Q is the mine air flow rate at the measurement point, m3/min; C is the concentration of the mixture in mine air at the measurement point, %. C = C1 + C2 + C3 + ... + Cn, where C1, C2, C3 ... Cn are the concentration of each hydrocarbon gas or vapour in the air at the measurement point according to laboratory analysis, % (by volume).
56. Where data from AGC systems on the mixture content in mine workings are used, the average flow rate of the mixture, m3/min, passing at the measurement point during the month is determined by the formula: , where Qi is the mine air flow rate at the measurement point, m3/min; Cti is the average daily concentration of the mixture according to AGC system data, % (by volume); nv is the number of measurements of mine air flow rate per month, units; nt is the number of average daily concentration values according to AGC system data during the month, units. Where data from monitoring the mixture content by portable instruments are used, the average flow rate of the mixture passing at the measurement point during the month is determined by the formula: , where CPi is the average daily concentration of the mixture according to portable instrument data, % (by volume); np is the number of average daily concentration values according to portable instrument data during the month, units. Where the mine air flow rate is monitored by AGC systems, in the formulas, the average daily values of mine air flow rate according to AGC system data are substituted for Qi, and the number of average daily mine air flow rate values according to AGC system data during the month is substituted for nv.
57. The average flow rate of the mixture passing at the measurement point during the year (month), m3/min, is determined by the formula: , where the sum is the sum of the mixture flow rates determined from the results of all measurements carried out at the given point during the year (month), m3/min; n is the number of mixture flow rate determinations for the year (month) accepted for the calculation, units. Where, in determining the mixture flow rate, the value I = 0 m3/min, such measurements are not taken into account in the calculation.
58. The flow rate of the mixture, Itr, m3/min, passing through the degasification pipeline at each measurement, is determined by the formula: , where the first sum is the sum of the mixture flow rates extracted from production wells of the production block, m3/min; the second sum is the sum of the mixture flow rates extracted from degasification wells, m3/min.
59. The average flow rate of the mixture, m3/min, passing through the degasification pipeline during the year (month), is determined by the formula: , where the sum is the sum of the mixture flow rates passing through the degasification pipeline at individual measurements during the year (month), m3/min; ntr is the number of measurements in the degasification pipeline during the year (month), units.
60. The average flow rate of the mixture released into each working or part thereof, in the section between the measurement points, m3/min: where there is no branching or merging of ventilation air currents between the two outermost measurement points, it is determined by the formula: , where the first term is the average flow rate of the mixture passing at the measurement points located at the end of the working (or its section), counting in the direction of the ventilation air current, m3/min; the second term is the average flow rate of the mixture passing at the measurement points located at the beginning of the working (or its section), counting in the direction of the ventilation air current, m3/min; where there is branching or merging of ventilation air currents between the outermost measurement points, it is determined by the formula: , where the first term is the total flow rate of the mixture entering the working between the starting and end measurement points, m3/min; the second term is the total flow rate of the mixture carried out of the working by branching ventilation air currents located between the starting and end points, m3/min.
61. The absolute and relative gas emission rates of the mine are determined monthly.
62. Calculations of the gas emission rates of production sections, wings, panels, blocks, levels and the mine are carried out by the head of the aerological safety service. Calculations of the gas emission rates of production sections, wings, panels, blocks and levels of the oil mine are retained for the entire period of operation of the oil mine.
63. To establish the gas hazard group of oil mines, special observations of the condition of the mine atmosphere are carried out annually in June-July.
64. Each observation is carried out while a constant regime of oil extraction, well drilling and mine working drivage operations is maintained. The duration of the special observations shall be not less than 15 days. Observations are carried out 3 times per day - once per shift.
65. Where the mine atmosphere of Group I hazard oil mines is found to contain higher hydrocarbon gases in a quantity of more than 10 per cent of the total volume, measures are taken to ensure the safety of persons working in the mine, control (repeat) mine air samples are taken, and the causes of this exceedance are established. Where the results of the repeat analyses confirm that, in the mine workings, there is an exceedance of the permissible content of higher hydrocarbon gases for Group I hazard, the oil mine is immediately transferred to Group II hazard. The transfer of oil mines from Group II hazard to Group I is carried out in the same order: where the analyses of the mine atmosphere show no higher hydrocarbon gases in a quantity exceeding 10 per cent of the total volume of hydrocarbon gases, the mine is transferred to Group I hazard.
1. Gas clearance of mine workings is carried out in accordance with the list of gas clearance actions for mine workings, approved by the technical manager of the oil mine. The gas clearance actions for mine workings determine the procedure for carrying out gas clearance operations and the measures ensuring the safety of their performance: de-energising the electrical equipment and cables in workings through which the return air current will pass - along the entire length of its path, including the return current of the wing (mine), and the evacuation of people from these workings; posting, in the fresh air current, of guards and prohibition signs at locations where people might approach the workings through which, during gas clearance, the return ventilation air current will pass. The gas clearance actions for mine workings indicate the gas clearance method, the procedure for continuous monitoring of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours by portable instruments in the return ventilation air current of the gassed working, and the locations and procedure for checking the total content of hydrocarbon gases and liquid hydrocarbon vapours in the workings after the completion of gas clearance.
2. Actions for degassing of mine workings are developed by the head of the aerological safety service before the commencement of development workings and are approved by the head of the heading section.
3. Actions for degassing of mine workings are communicated to the employees and workers of the heading section and other mine sections who carry out mining operations in these workings, to the employees of the aerological safety service, and to the employees organising and ensuring mining operations at the mine. One copy of the actions for degassing of mine workings is kept by the mine dispatcher of the oil mine and by the head of the aerological safety service.
4. Degassing of isolated workings and sections is carried out during non-working shifts by units of the professional emergency rescue service (PASF) and members of the auxiliary emergency rescue team of the oil mine. Actions for degassing of isolated workings and sections are approved by the technical manager of the oil mine and agreed with the commander of the PASF unit servicing the oil mine. The actions for degassing of isolated workings and sections set out: data on the condition of the isolated workings subject to degassing under the actions; a description of the isolation structures; the parameters of the mine atmosphere at the isolation structures and in the isolated workings, including the results of laboratory analyses and samples; a ventilation diagram of the mine workings in which the isolation structures are located; a diagram of air movement from the workings and sections being degassed; a description of the ventilation structures in the mine workings adjoining those being degassed; a diagram of the placement of posts and signs restricting access of persons to the workings being degassed and to the workings with the return air current from the workings being degassed; a diagram of the location of persons in the mine and their routes of egress to the surface. The actions for degassing of isolated workings and sections contain the procedure for: ensuring the power supply of the mine during degassing operations; carrying out degassing operations in isolated workings and sections; monitoring the total concentration of hydrocarbon gases and liquid hydrocarbon vapours in the return air current from the workings being degassed; admission of employees to the mine workings; communication between the employees carrying out the degassing actions and the person in charge of the degassing operations; the use of technical means and devices used in carrying out degassing operations; inspection of the degassed workings and monitoring the total concentration of hydrocarbon gases and liquid hydrocarbon vapours in them; completion of degassing operations.
5. For a development working ventilated by a local ventilation fan (LVF), the head of the aerological safety service determines the reference gassing time - the time during which, in the absence of ventilation, accumulations of hydrocarbon gases and liquid hydrocarbon vapours form in the working with a concentration exceeding 45 per cent of the lower flammability limit (LFL) of the mixture, or 2 per cent (by volume) in oil mines of hazard group I, or 1.6 per cent (by volume) in oil mines of hazard group II. The reference gassing time of a development working is established by conducting a trial gassing of the working or is calculated taking into account the actual absolute gas content of the working. The reference gassing time of a development working is established monthly. Trial gassing is not carried out in development workings whose reference gassing time is less than 20 minutes.
6. Remote switching-on of the LVF shall not be permitted where ventilation of a development working has been absent for a period exceeding its reference gassing time. Where ventilation of a development working has been absent for a period not exceeding its reference gassing time, the LVF is switched on remotely.
7. Degassing devices are used to carry out actions for the degassing of development workings. A degassing device is installed in the ventilation duct in the dead-end part of the development working, 5-10 m from its mouth. The device shown in Figure 1 of this Appendix is used for degassing dead-end mine workings. The device consists of a cylindrical or rectangular branch pipe 1 with a valve 2 fitted with a seal made of porous rubber. Fig. 1. Device for degassing dead-end mine workings: (a), (b) - diagrams of the device; (c) - installation diagram; 1 - branch pipe; 2 - valve; 3 - rollers; 4 - cable; 5 - manual (electric) winch. The air flow rate at the face of the working is regulated by changing the position of valve 2 by means of cable 4 and the manual (electric) winch. The winch is installed in a working with a fresh air current, not less than 20 m from the mouth of the development working. The degassing procedure is as follows: valve 2 closes off the cross-section of branch pipe 1; the LVF is switched on for continuous operation; the air flow rate supplied to the face of the development working is gradually increased; continuous monitoring of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours is ensured by portable monitoring instruments at the mouth of the development working; where the total concentration of hydrocarbon gases and liquid hydrocarbon vapours at the monitoring point is 45 per cent or more of the LFL of the mixture, or 2 per cent or more (by volume) in oil mines of hazard group I, or 1.6 per cent or more (by volume) in oil mines of hazard group II, the air flow rate supplied to the face of the development working is reduced. In workings ventilated by two or more ventilation ducts, the degassing device is fitted on one of them. The LVF installed on the ventilation duct fitted with the degassing device is switched on first. The second LVF, installed on the ventilation duct without a degassing device, is switched on after the valve of the degassing device has been fully opened, provided that the total concentration of hydrocarbon gases and liquid hydrocarbon vapours at the mouth of the development working is less than 45 per cent of the LFL of the mixture, or 2 per cent (by volume) in oil mines of hazard group I, or 1.6 per cent (by volume) in oil mines of hazard group II.
8. The person in charge of degassing operations in mine workings: notifies the mine dispatcher of the completion of the actions and the commencement of degassing operations; ensures that the total content of hydrocarbon gases and liquid hydrocarbon vapours in the return air current from the gassed working does not exceed 45 per cent of the LFL of the mixture, or 2 per cent (by volume) in oil mines of hazard group I, or 1.6 per cent (by volume) in oil mines of hazard group II; after degassing of the mine working, checks the total content of hydrocarbon gases and liquid hydrocarbon vapours in the degassed working using portable monitoring instruments; takes measures to eliminate the causes that gave rise to the gassing; notifies the mine dispatcher of the completion of degassing and the elimination of the causes that gave rise to it.
9. The LVF may be switched on during degassing of development workings after the total concentration of hydrocarbon gases and liquid hydrocarbon vapours at its installation point has been reduced to 10 per cent of the LFL of the mixture, or 0.5 per cent (by volume) in oil mines of hazard group I, or 0.4 per cent (by volume) in oil mines of hazard group II.
10. Mining operations in degassed workings resume by decision of the technical manager of the oil mine after the causes of the gassing have been investigated and eliminated.
11. Emergency gassing of mine workings lasting 6 hours or more is investigated in accordance with industrial safety legislation. Emergency gassing of mine workings lasting less than 6 hours is investigated by employees of the oil mine (of the oil mine) in the procedure established by this Appendix.
12. Emergency gassing of mine workings lasting up to 30 minutes is investigated under the direction of the head of the aerological safety service or his deputy (assistant); lasting more than 30 minutes but less than 6 hours, under the direction of the technical manager of the oil mine or his deputy. Investigations of emergency gassing are carried out with the participation of the head of the structural subdivision, or his deputy, in whose workings the gassing occurred. Emergency gassing of mine workings lasting less than 6 hours is investigated within 24 hours.
13. At oil mines hazardous by gas equipped with automated gas control (AGC) systems, on the basis of data on the total content of hydrocarbon gases and liquid hydrocarbon vapours in mine workings obtained by means of these systems, the following are investigated: exceedances of the total content of hydrocarbon gases and liquid hydrocarbon vapours above the trip set-points, irrespective of their duration, in which the AGC system failed to perform the automatic gas protection function - automatic disconnection of electric power in the monitored working; exceedances of the values of the total content of hydrocarbon gases and liquid hydrocarbon vapours equal to the trip set-points plus the absolute error of the monitoring sensor, irrespective of their duration; exceedances of the total content of hydrocarbon gases and liquid hydrocarbon vapours, irrespective of their duration, recorded by a single sensor 3 or more times within 6 hours.
14. In investigating emergency gassing of mine workings, the causes of the gassing, its duration, and the maximum total concentration of hydrocarbon gases and liquid hydrocarbon vapours in the gassed working are established.
15. The results of the investigation are recorded in a report on the investigation of gassing of mine workings, approved by the technical manager of the oil mine. The head of the structural subdivision in whose workings the gassing occurred is familiarised with the results of the investigation of the emergency gassing and with the actions for its prevention.
16. The following are recorded as gassing of mine workings: cases of exceedance of the standards for the total concentration of hydrocarbon gases and liquid hydrocarbon vapours; gas blowers and outbursts of hydrocarbon gases and liquid hydrocarbon vapours; cases of exceedance of the standards for the concentration of carbon dioxide; cases of exceedance of the concentration of carbon monoxide, nitric oxide, nitrogen dioxide, sulphur dioxide, hydrogen sulphide and other harmful gases.
17. All cases of exceedance of the standards for the total concentration of hydrocarbon gases and liquid hydrocarbon vapours in respect of which an investigation has been carried out in accordance with paragraphs 1-6 of this Appendix are recorded as gassing.
18. The date and time of the gassing, its duration and the total content of hydrocarbon gases and liquid hydrocarbon vapours in the gassed working are taken from the data of the AGC systems and (or) on the basis of oral information received from the persons who discovered the gassing.
19. In the absence of information on the total concentration of hydrocarbon gases and liquid hydrocarbon vapours in unventilated development workings, the following are classified as gassed workings: in mines not hazardous by gas - unventilated development workings more than 10 m long where their ventilation has ceased for 30 minutes or more; in mines hazardous by gas - unventilated development workings more than 6 m long where their ventilation has ceased for 5 minutes or more.
20. Where several mine workings are simultaneously gassed, irrespective of the causes giving rise to it, the gassing of each working is recorded.
21. Two or more exceedances of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours within 6 hours, caused by a single cause, are recorded as a single gassing. In this case, the gassing time of the working is taken from the time of commencement of the first exceedance of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours to the time of completion of the last exceedance of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours.
22. Exceedances of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours recorded by two or more sensors of the AGC system in the workings of a production block or in a development working, caused by a single cause, are recorded as a single gassing.
23. Exceedances of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours in the workings of a production block are recorded as a single gassing.
24. Readings of hydrocarbon gas and liquid hydrocarbon vapour monitoring sensors received by the AGC system during technical and metrological maintenance of the sensors, and information received from these sensors where their normal operation and (or) the requirements for operation of the AGC system have been infringed, are not recorded as gassing of mine workings.
25. Cases of infringement of the normal operation of the AGC system and of the requirements for its operation are investigated by employees of the oil mine. The causes of infringements of the normal operation of the AGC system and of the requirements for its operation are entered in the AGC system operating log.
26. Cases of exceedance of the total concentration of hydrocarbon gases and liquid hydrocarbon vapours caused by the performance of technical and metrological maintenance of the AGC system are recorded in the AGC system operating log and are not investigated.
27. Within 24 hours, the head of the aerological safety service records gassing of mine workings in the gassing log; gas blowers of hydrocarbon gases and liquid hydrocarbon vapours in the log of hydrocarbon gas and liquid hydrocarbon vapour blowers; and elevated concentrations of carbon dioxide in the log of elevated carbon dioxide concentrations.
28. Analysis of the causes of gassing of mine workings is carried out by the head of the aerological safety service once every 6 months. The results of the analysis are approved by the technical manager of the oil mine.
29. In analysing gassing, the following are established: the number of gassing incidents that occurred during the period analysed at production sections, including by cause of occurrence; the number of gassing cases that occurred during the period analysed in development workings, including by cause of occurrence; the average duration of gassing of production blocks and development workings; the number of emergency gassing incidents by type; the frequency of emergency and technological gassing of production blocks and development workings (the gassing frequency being the ratio of the number of gassing incidents occurring during a period of time to the average operating number of production blocks and dead-end workings, respectively); the implementation of actions for the prevention of gassing of mine workings over the preceding 6 months.
30. The results of the analysis of the causes of gassing of workings are used in developing actions for the prevention of gassing of mine workings.
31. Actions for the prevention of gassing of mine workings are developed by the head of the aerological safety service. The actions for the prevention of gassing of mine workings include methods of preventing gassing, providing for: a change to the ventilation diagram of the gassed working; an increase in the air flow rate in the gassed working; a reduction in gas emission into the gassed working. The actions for the elimination of gassing of mine workings, upon detection of local and layered accumulations of hydrocarbon gases and liquid hydrocarbon vapours, provide for: the use of technical devices that increase the speed of the ventilation air current in the gassed part of the working (air ejectors, water-air ejectors, fans with pneumatic or hydraulic drive, turbulising ducts, inclined baffles, ventilation stoppings); an increase in air speed.
32. The procedure for applying methods of prevention and elimination of gassing is established by an organisational and administrative document of the oil mine.
1. The planned practical inspection of emergency ventilation regimes provided for in the action plan is carried out to determine whether the ventilation air current can be passed through the mine workings of the oil mine under the reversal ventilation pattern and under the other ventilation patterns provided for in the action plan.
2. The planned practical inspection of emergency ventilation regimes provided for in the action plan is carried out twice a year, in the summer and winter periods, when the action plan is being developed, when the ventilation patterns of the mine, wing or level are changed, and when the main fan installation (MFI) is replaced.
3. When carrying out the planned practical inspection of emergency ventilation regimes provided for in the action plan, the performance indicators of the MFI in reversal mode, the air distribution and the content of hydrocarbon gases and liquid hydrocarbon vapours in the workings of the oil mine under the reversal ventilation regime are determined. The performance indicators of the MFI in normal mode, the air distribution and the total content of hydrocarbon gases and liquid hydrocarbon vapours in the workings of the oil mine under the normal ventilation regime are determined when carrying out the planned practical inspection of emergency ventilation regimes provided for in the action plan, before the MFI is switched to reversal operating mode and after it is switched back to normal operating mode. For other emergency ventilation regimes of the oil mine, the use of which enables all the ventilation patterns provided for in the action plan to be implemented (special ventilation regimes), the direction of movement, the air flow rate and the total content of hydrocarbon gases and liquid hydrocarbon vapours are determined only in the workings for which an emergency ventilation regime is provided.
4. When carrying out the planned practical inspection of emergency ventilation regimes provided for in the action plan, the serviceability and operation of the reversal, switching and sealing devices of the MFI are checked. The check of the serviceability of the reversal, switching and sealing devices is carried out with the fans stopped, without starting them in reversal mode, by switching over from one fan to another. Monitoring of the condition of the reversal, switching and sealing devices is carried out by the chief mechanical engineer of the oil mine or a person appointed by him.
5. The plan for carrying out the planned practical inspection of emergency ventilation regimes provided for in the action plan (hereinafter - the emergency ventilation regime inspection plan) is approved by the technical manager of the oil mine and agreed with the commander of the PASF unit servicing the oil mine. The emergency ventilation regime inspection plan is sent to the territorial office of Rostechnadzor and to the PASF unit servicing the mine.
6. The emergency ventilation regime inspection plan is developed using computer calculations of the mathematical model of the mine ventilation network. The emergency ventilation regime inspection plan contains: the procedure and operating regimes of the MFI; the points for monitoring the total content of hydrocarbon gases and liquid hydrocarbon vapours and for taking air flow rate measurements in the workings for which the action plan provides for reversal of the ventilation air current; a list of the ventilation structures for which air leakages are determined during reversal of the ventilation air current.
7. The planned practical inspection of emergency ventilation regimes provided for in the action plan is carried out under the direction of the technical manager of the oil mine.
8. The number of persons required to carry out the planned practical inspection of emergency ventilation regimes provided for in the action plan, and their location in the mine, are established by the technical manager of the oil mine in accordance with the emergency ventilation regime inspection plan.
9. The time for reversal of the ventilation air current is established at not less than the time required for persons to leave the most remote working for workings with a fresh air current or for the surface.
10. When carrying out the planned practical inspection of emergency ventilation regimes provided for in the action plan, the air flow rate and the total concentration of hydrocarbon gases and liquid hydrocarbon vapours are measured in the workings for which the action plan provides for reversal of the ventilation air current. Measurements are taken with portable instruments at 10-15 minute intervals, starting from the moment the direction of the air current in the working changes until the moment the total concentration of hydrocarbon gases and liquid hydrocarbon vapours in it reaches 45 per cent of the LFL of the mixture, or 2 per cent (by volume) in oil mines of hazard group I for hydrocarbon gases, or 1.6 per cent (by volume) in oil mines of hazard group II for hydrocarbon gases, or until the end of the reversal regime. In the working, at a total concentration of hydrocarbon gases and liquid hydrocarbon vapours of 40 per cent of the LFL of the mixture, or 1.7 per cent (by volume) in oil mines of hazard group I for hydrocarbon gases, or 1.3 per cent (by volume) in oil mines of hazard group II for hydrocarbon gases, samples of the mine air are taken simultaneously with the measurements for checking its composition. Measurements of the air flow rate, the total concentrations of hydrocarbon gases and liquid hydrocarbon vapours, and the concentrations of carbon dioxide and other harmful gases are taken by employees of the aerological safety service. Sampling for checking the composition of the air is carried out by employees of the PASF in the presence of employees of the aerological safety service at the points determined by the technical manager of the oil mine. Checking the composition of the air is performed in the gas-analytical laboratories of the PASF.
11. In the workings in which measurements of the air flow rate and the total concentration of hydrocarbon gases and liquid hydrocarbon vapours are taken, the time of the change in the direction of movement of the ventilation air current is established by the employees of the oil mine participating in the reversal.
12. Control and supervision over compliance with industrial safety requirements during the planned practical inspection of emergency ventilation regimes provided for in the action plan are carried out by representatives of the territorial office of Rostechnadzor.
13. When carrying out the planned practical inspection of emergency ventilation regimes provided for in the action plan, the condition of the MFI electric motors is monitored. Operation of the MFI electric motor in overload mode shall not be permitted.
14. When carrying out the planned practical inspection of emergency ventilation regimes provided for in the action plan, the electric power supply in the oil mine is disconnected. The procedure for supplying electric power to the buildings of the surface complex of the oil mine, the MFI buildings, and the mine hoisting and drainage installations is determined when the plan for carrying out the inspection of emergency ventilation regimes is developed, and is approved by an organisational and administrative document of the oil mine.
15. After the planned practical inspection of emergency ventilation regimes provided for in the action plan has been carried out, the employees of the aerological safety service check the total content of hydrocarbon gases and liquid hydrocarbon vapours and the content of carbon dioxide in the mine workings. The check is carried out not earlier than 30 minutes after normal ventilation of the oil mine has been restored. Permission to carry out degassing operations in development workings is given by the technical manager of the oil mine. Degassing operations in development workings are carried out where the total concentration of hydrocarbon gases and liquid hydrocarbon vapours at the points of installation of local ventilation fans and the electrical installations providing their power supply is within the permissible standards. The decision to complete the planned practical inspection of emergency ventilation regimes provided for in the action plan, and to resume mining operations, is taken by the technical manager of the oil mine.
16. The report of the planned practical inspection of emergency ventilation regimes provided for in the action plan (hereinafter - the report) is approved by the technical manager of the oil mine and sent to the territorial office of Rostechnadzor and to the PASF units servicing the oil mine. Ventilation diagrams of the mine in reversal and emergency regimes are attached to the report. The report is kept at the aerological safety section for not less than 1 year.
17. Based on the results of the reversal of the ventilation air current, the head of the aerological safety service develops ventilation diagrams of the mine in reversal and emergency regimes. The ventilation diagrams of the mine in reversal and emergency regimes are approved by the technical manager of the oil mine and are kept at the aerological safety section for one year.
1. The ventilation plan is drawn up by the head of the aerological safety service and approved by the technical manager of the oil mine.
2. The ventilation plan consists of a graphic part and a text part. The graphic part of the ventilation plan consists of: a ventilation diagram of the oil mine, including diagrams of the ventilation channels of the MFI and the auxiliary fan installation (AFI); a diagram of ventilation connections. The text part of the ventilation plan consists of: the results of the calculation of the mathematical model of the mine ventilation network at the beginning of the period under review; an explanatory note to the ventilation plan; actions for ensuring ventilation of the mine.
3. The ventilation plan is drawn up in accordance with the actual state of mining operations. The ventilation plan is corrected by the head of the aerological safety service within 24 hours after the commencement and completion of driving development workings, a change in the direction of their driving, the erection and dismantling of ventilation devices, isolation structures, fire-proof arches and stoppings, a change in the installation points of the LVF, the operating regimes of the MFI and the AFI, or the direction of movement of the ventilation air currents.
4. The following are shown on the ventilation diagram of the oil mine: For the MFI and AFI: their types, actual and design outputs (capacities), actual and design pressures and the possibility of reversal are indicated; air cooling devices, indicating their type and actual cooling capacity; heater units, indicating the heater system and heating surface; ventilation devices; isolation structures; fire-proof arches and stoppings; the direction of air movement through the mine workings: the direction of movement of the fresh ventilation air current is indicated by a red arrow, and of the return ventilation air current by a blue arrow; the points of air flow rate measurement, indicating the number of the measuring station, the cross-sectional area of the working, the speed of air movement and its actual flow rate; for the LVF, their types, actual outputs, pressures and air flow rates in the workings ahead of the LVF are indicated; for the ventilation ducts, their diameters are indicated; stationary sensors of the AGC system, indicating the trip set-point; telephones.
5. The following are indicated on the ventilation diagram of the oil mine: the design and actual flow rate of air entering the mine, the wings, panels, blocks and levels; the design and actual flow rate of air leaving the mine, the wings, panels, blocks and levels; the design and actual flow rate of air entering the production blocks; the design and actual flow rate of air leaving the production blocks; the design and actual flow rate of air entering the faces of development workings and the LVF installation points; the design and actual flow rate of air leaving development workings; the design and actual external air leakages; the design and actual internal air leakages; the design and actual air flow rate for ventilating chambers and workings being maintained; the actual air speed in production and dead-end workings. The design air flow rate is shown on the mine ventilation diagram in red, and the actual flow rate in black. The date of measurement is indicated for the actual air flow rate. The placement of the data provided for in this paragraph in tables on standard sheets of A3 or A4 paper is carried out by decision of the technical manager of the oil mine. Data placed in tables on standard sheets of A3 or A4 paper are not shown on the mine ventilation diagram.
6. The following data are set out in tabular form on the ventilation diagram of the oil mine: the hazard group of the oil mine for hydrocarbon gases; the absolute gas content of the mine; the relative gas content of the mine; the design and actual flow rate of air entering the mine; the design and actual absolute and relative air leakages; the category of the mine for ventilation stability; the volumetric (in per cent by volume) and mass (mg/l) composition, determined by laboratory testing, of the mixture of hydrocarbon gases and liquid hydrocarbon vapours that may be released into the mine air of the oil mine at a temperature below 27.85°C, and in the temperature range from 27.85°C to 36.07°C; the dust hazard;
7. The following are indicated on the diagram of ventilation connections: node numbers; branch numbers. Where nodes and branches are shown on the ventilation diagram, a diagram of ventilation connections is not drawn up.
8. The results of the calculation of the mathematical model of the mine ventilation network at the beginning of the period under review are set out in the form of tables.
9. The explanatory note is drawn up annually when preparing the plan (production programme) for the development of mining operations.
10. The explanatory note contains the following data: a list of the reservoir beds and their host rocks in respect of which a propensity to spontaneous combustion, to dynamic phenomena, and a dust hazard have been identified in the course of operation; the absolute and relative gas emission rate of the shaft; the expected and actual absolute gas emission rates of the development workings and production blocks; a description of the method and layout of shaft ventilation; the design and actual air flow rate for ventilating the oil shaft; the parameters and performance characteristics of the main mine fans and auxiliary ventilation units; a list of the development workings ventilated by local ventilation fans, and the types of local ventilation fans used; the number of production blocks subject to ventilation (separately for driving, equipping and operation); the number of instances of gas accumulation in the workings of production blocks and dead-end workings in the calendar year preceding the year for which the explanatory note is drawn up, an analysis of the causes of gas accumulation and measures for preventing gas accumulation. The description of the parameters and performance characteristics of the main mine fans and auxiliary ventilation units sets out the following data: the types of main mine fans and auxiliary ventilation units, including duty and standby units; the actual output and pressure of the main mine fans and auxiliary ventilation units; the maximum possible output of the main mine fans and auxiliary ventilation units when operating on the existing shaft ventilation network; the rotational speed of the impellers; the setting angles of the impeller blades, and of the guide and straightening vanes; the possibility and method of switching the main mine fans and auxiliary ventilation units to reverse ventilation mode. The actual output and pressure of the main mine fans and auxiliary ventilation units are plotted on graphs of fan output against pressure (hereinafter referred to as the aerodynamic characteristics). The maximum possible output of the main mine fans and auxiliary ventilation units when operating on the existing shaft ventilation network is determined graphically from their aerodynamic characteristics.
11. The ventilation connection diagram and the results of calculation of the mathematical model of the mine ventilation network are included in the explanatory note.
12. Actions for ensuring ventilation of the oil shaft are drawn up annually when preparing the plan (production programme) for the development of mining operations.
13. When developing the actions for ensuring ventilation of the oil shaft, the results of mathematical modelling of shaft ventilation are used.
14. The actions for ensuring ventilation of the oil shaft set out data on the results of calculation of the air flow rate required for ventilation at the beginning of the planned period and at the stage with the most difficult ventilation conditions. The actions for ensuring ventilation of the oil shaft set out the actual indicators characterising the state of ventilation: the air flow rate in the workings of production blocks and in development workings, internal and external air leakages, the aerodynamic resistance of the mine ventilation network, the gas emission rate of the mine workings, and the results of calculations of the mathematical model of the mine ventilation network, showing the need for implementing the contemplated actions. When developing the actions for ensuring ventilation of the shaft, provision is made for: changes to the shaft ventilation layout enabling separate ventilation of the mine workings of production blocks and development workings; a reduction in internal and external air leakages; a reduction in the aerodynamic resistance of the mine workings; replacement of the main mine fans; a reduction in the length of ventilation workings, the sinking of ventilation shafts and boreholes, and the use of flank ventilation layouts; occasional, scheduled work by personnel in workings with a temperature above 26 °C.
1. In oil shafts, monitoring of the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons by portable automatic instruments shall be carried out: in the face areas of dead-end workings up to 50 m in length, and, where there is no electric power supply, irrespective of their length; at places where personnel work in workings with a return air current on beds with gas blowers; at extraction machines in areas hazardous for gas blowers; on electric locomotives.
2. Portable automatic instruments for monitoring the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons are placed as follows: in oil shafts of hazard group I: in dead-end workings - at a distance of not more than 30 cm from the roof, 3 - 5 m from the face on the side opposite the ventilation duct; on the return air currents of production or drilling areas - at the roof of the working at places where personnel work; in oil shafts of hazard group II - in accordance with the manufacturer's operating documentation and the actions approved by the technical manager of the organisation (shaft).
3. Portable automatic instruments for monitoring the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons are suspended in such a way that the air flow approaches from the side opposite the front panel of the instrument.
4. In oil shafts, monitoring of the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons in the mine atmosphere is carried out by stationary automatic instruments: in the face areas and in the return air currents of dead-end workings more than 50 m in length in which electric power is used. Where mobile substations are present in the dead-end part of the working - at the substations; in the return air currents of areas hazardous for gas blowers; in the return air currents of workings (areas) where oil wells are being drilled and/or oil is being produced.
5. Sensors of stationary automatic monitoring instruments are installed: in the return air currents of dead-end workings - at a distance of 10 - 20 m from the mouth of the working; in the face area of dead-end workings - under the roof at a distance of 3 - 5 m from the face on the side opposite the ventilation duct; at mobile substations - at a distance of 10 - 15 m from the substation towards the face; at local ventilation fans with electric motors - at a distance of not less than 10 m from the fan on the face side of the dead-end working; in the return air currents of areas hazardous for gas blowers; in the return air currents of workings where oil wells are being drilled and/or oil is being produced.
1. The placement and connection of electrical equipment in dead-end workings are carried out in accordance with the design of the automatic gas control (AGC) system.
2. Power supply to the duty and standby local ventilation fans in oil shafts hazardous for gas is provided from mobile substations. The electrical network of the standby local ventilation fan is separated from other electricity consumers of the mobile substations by means of circuit breakers.
3. When mobile substations are installed in workings ventilated by local ventilation fans, apparatus for the automatic monitoring of the content of hydrocarbon gases and vapours of liquid hydrocarbons and for monitoring the air output of the fan is installed, which acts on the switchgear of that substation installed on the fresh air current. In the electrical network with a voltage above 1140 V from which the mobile substation is supplied, protection against single-phase earth faults is installed.
4. The group apparatus and other apparatus connected into the network ahead of it are installed on the fresh air current in such a way that, when the dead-end working is cleared of gas, the air current leaving it passes not closer than 10 m from that apparatus.
5. Electrical apparatus (magnetic starters, circuit breakers, high-voltage cells, group contactors in switchgear) having an interlocking disconnector, no-volt protection and intrinsically safe parameters of the remote control circuit are used as the group apparatus.
6. Where apparatus for monitoring air flow rate and the content of hydrocarbon gases and vapours of liquid hydrocarbons is used, the switching-on and switching-off of the group apparatus is carried out remotely by means of a push-button station located 20 - 50 m from the face of the dead-end working, or by telemechanical control by the mine dispatcher of the oil shaft on commands transmitted by telephone from the face of the dead-end working, with subsequent feedback from the mine dispatcher. Remote control of the group apparatus is carried out via a three-wire circuit. Where a high-voltage cell with spark-hazardous parameters of the control circuit is used as the group apparatus, the cell is switched on from its place of installation on commands transmitted by telephone from the mobile substation in the dead-end working. In that case, the operating handle of the cell is removed, and it is controlled by means of a push-button station located near the cell. Where the group apparatus is controlled telemechanically, telemetry measurement is carried out with recording in the archive and in the AGC operator's log. The log indicates the date and time of switching-on and switching-off of the group apparatus, the surname of the person who gave the command, data on the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons in the return air current before the command is executed, and the surname and signature of the person who executed the command. Control of group apparatus is carried out by specially designated persons holding the appropriate electrical safety qualification group.
7. To ensure continuous operation of the local ventilation fan, its starter is connected to the input of the general circuit breaker of the section distribution point by means of a separate circuit breaker not having no-volt protection. For the same purpose, electricity consumers not technologically connected to one another are connected to separate distribution points with circuit breakers installed at the input of each of them. Where magnetic starters having an interlocking disconnector in a separate explosion-protected compartment are used as the group apparatus and for controlling the local ventilation fan, circuit breakers are not installed ahead of it, provided the protection of those starters is ensured by a circuit breaker installed in the mobile substations or in the distribution point. A circuit breaker ahead of the group apparatus may not be installed if the distance between the latter and the general circuit breaker of the section distribution point is not more than 20 m.
8. Planned shutdowns of the local ventilation fan in connection with the repair of electrical equipment are carried out only with the written permission of the technical manager of the oil shaft or the person acting in that capacity. In the event of an emergency shutdown of the local ventilation fan, the mine dispatcher of the oil shaft is notified, who informs the technical manager of the oil shaft or the person acting in that capacity accordingly.
9. Power supply to the air flow rate monitoring apparatus is provided from the fan starter, and to the apparatus for monitoring the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons - from the input of the general breaker. The length of the cables for the electrical interlocking of the actuating devices of that apparatus with the group apparatus shall not exceed 20 m, if the interlocking circuit does not have protection against conductor short-circuiting.
10. Apparatus for monitoring air flow rate and the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons shall operate continuously. Where the normal ventilation mode of a dead-end working is disrupted, or where the total concentration of hydrocarbon gases and vapours of liquid hydrocarbons at the monitoring points exceeds the maximum total concentrations set out in Appendix No. 5 to these Rules, the apparatus, together with the group apparatus, automatically disconnects the voltage from all electrical equipment located in the dead-end working. The group apparatus is automatically disconnected when the local ventilation fan starter is switched off, for which purpose electrical interlocking is provided between those apparatus.
11. Where faults are detected in the apparatus for monitoring air flow rate and automatic monitoring of the content of hydrocarbon gases and vapours of liquid hydrocarbons, or in the cables connected to that apparatus, or while that apparatus is being moved, work on driving mine workings shall not be permitted, and measures are taken to remedy the faults.
12. The length of the cable for supplying power to the air flow rate monitoring apparatus, automation equipment and other separately installed equipment from a spark-hazardous source with a voltage of up to 42 V built into magnetic starters and control stations shall not exceed 20 m. The use of tee couplings and similar devices shall not be permitted for connecting such electrical equipment in a network with a voltage of up to 42 V.
13. Where ventilation of a dead-end working is disrupted, or where individual sections of it become filled with gas, the circuit breaker shall disconnect the voltage from the electrical equipment of the dead-end working. A warning sign reading "Do not switch on - working filled with gas!" shall be posted on the disconnector handle of the apparatus locked in the off position. That sign may be removed only after the working has been completely cleared of gas and the condition of the electrical equipment has been checked.