SY 6432-1999 Well control requirements for shallow water petroleum operations
Some standard content:
I0S 13.100
Reference number: 4107—1999
Petroleum and natural gas industry standard of the People's Republic of China SY 64321999
Well control requirements for shallow sea petroleum operations
Well control rcquirements for shallow sea petroleum operations1999－09-14Published
National Petroleum and Chemical Industry
2000－04-01Implementation
SY 6432--1999
Cited standards
One requirement
Drilling and drilling operations
Parallel operations
Oil (gas) production operations
Water (gas) injection operations
Emergency treatment
SY 64321999
This standard is formulated to regulate the design, operation and management of control systems in shallow-water oil operations and to prevent blowout accidents. This standard is proposed by China National Petroleum Corporation and is managed by the Petroleum Industry Safety Professional Standardization Technical Committee. The main drafting units of this standard: Shengli Shizhou Administration Oil Production Technology Research Institute, Ocean Shishan Development Company, Tanyang Drilling Company, Downhole Operation Company, Technical Supervision Department,
The main drafters of this standard Tu Minxuan
Zhang Xuemei
Li Xuejing
Zhao Xijiang
Zhang Xiaoyou
Ren Qinghe
1 Scope
Petroleum and Natural Gas Industry Standard of the People's Republic of China Well Control Requirements for Shallow Sea Petroleum Operations
Well control reuirements for shallow sea petroleum operationsSY 64321999
This standard specifies the well control requirements for oil (gas) drilling, downhole operations, oil (gas) production operations, water (gas) injection operations, etc. in shallow sea areas.
This standard applies to petroleum operations in shallow sea waters. 2. Referenced Standards
The provisions contained in the following standards become the provisions of this standard through reference in this standard. When this standard is released, all smaller versions are valid. All standards are subject to revision. Parties using this standard should explore the possibility of using the latest version of the following standards: SY/T 4807-92 Recommended practice for design, installation, maintenance and operation of downhole safety chest systems SY 3053.1-92
SY 5053.291
SY/ 570-95
SY 5742-19y5
SY/I 5964-94
Surface blowout preventer and control device
Surface blowout preventer and control device Control device test Wellhead device performance inspection
Petroleum and natural gas drilling well control safety technology assessment management rules Drilling well control device assembly matching specification
SY/T 6120-1995 Technical regulations for blowout prevention in downhole operations SY 6307--1997
SY SY 6321—1997
Safety regulations for drilling and drilling in shallow waters
Safety regulations for oil and gas exploration and submersion operations in shallow waters
SY 6345—1998
Safety qualifications for personnel in shallow water well control
Requirements for well control in offshore oil operations Safety Office of offshore oil operations, Ministry of Energy of the People's Republic of China November 3, 1988 3 General requirements
3.1 Personnel in shallow water well control operations shall be trained and certified in accordance with SY5742 and SY6345. 3.2 A well control emergency plan shall be formulated before operation. 3.3 Conduct well control drills regularly. Well control for drilling and submersion operations shall be drilled once every 7 days, well control for submersion operations shall be drilled once every 7 days, and well control for oil and gas production operations shall be drilled once every 15 days. Keep records. 34 The installation, testing, inspection, and operation of well control equipment shall be recorded and preserved. 4 Drilling and drilling operations
4.1 Well control design
The design contents include but are not limited to the following contents: a) Full formation pressure gradient, formation fracture pressure gradient, shallow gas layer data, stratified pressure data of the block; b) Drilling fluid density; c) Well structure; d) Requirements for well control devices for previous drillings; Approved by the State Administration of Petroleum and Chemical Industry on September 14, 1999 and implemented on April 1, 2000; e) Conventional blowout prevention measures; [) Special well control requirements; SY 6432-1999
) Requirements for formation pressure while drilling and drilling fluid density adjustment: The well control design shall be approved by the technical department authorized by Party A. 4.2 Control device
4.2.1 Matching
The matching of well control device shall comply with the provisions of 7.2 to 7.5 of SY6307-1997, and shall meet the following requirements: 4.2.1.1 Devices fixed on drilling facilities) Remote control console: at least one of electric, pneumatic or other drive modes shall be adopted; b) Energy storage device: shall meet the requirements when the combination of BOP is "annular BOP + double gate BOP + piton + single gate BOP";
c) Driller's console;
) Throttle pressure and pressure: rated working pressure shall not be less than 70MPa; e) Gas separator and venting pipeline: the rated separation unit of gas separator shall be greater than 50L per minute, and the true diameter of venting pipeline shall not be less than 1271
) Various connecting pipelines: shall be fireproof and antifreeze. The above technical specifications shall comply with the requirements of SY/T 5964. 4.2.12 Calculation of equipment for non-rigid drilling and drilling facilities a) Blowout preventer: Blowout preventers of different pressure levels should be selected according to the formation pressure of the well being drilled. The combination of blowout preventers should comply with the provisions of 2.3 of the "Ocean Rock Operation Control Requirements"; b) Flow diverter: For construction wells predicted to have gas formations, flow diverters should be used; ) Casing head: Construction wells should use casing heads with the same pressure level as the blowout preventer used; d) Exploration wells should be equipped with comprehensive logging instruments. 4.2.1.3 Control and drilling auxiliary facilities
) Drilling internal blowout preventer;
b) Control and monitoring instruments:
c) Combustible gas and toxic gas alarm devices; d) Drilling fluid treatment equipment:
) Drilling fluid injection equipment:
f) Replacement of rock storage tanks;
g) Standby blowout prevention materials, etc.
4.2.2 Installation
The control device should be installed according to the engineering design, and the connection should be firm, in compliance with the regulations, safe and reliable. 4.2.3 Inspection
4.2.3.1 Factory Inspection
All accessories of the drilling and control device should be inspected and can be used only after obtaining a qualified inspection certificate. 4.2.3.2 On-site initial installation pressure test
a) It is advisable to use a pressure test pump; use the plug or the pressure test plug to conduct a clean water pressure test; b) Test the pressure values of various devices, and the pressure drop within 30 minutes is less than 0.5MPa. Test the annular blowout preventer, gate blowout preventer, and throttling pressure gauge of each gate; d) Before all blowout preventers are tested at high pressure, a low pressure test of 1.4-3.5MFa is performed. 4.2.3.3 Pressure test in the process
During the process, the BOP shall be pressure tested regularly. The pressure test time is: 2
a) After each cementing and before drilling cement; b) Every one week during exploration and normal drilling;
e) 50m before drilling the oil and gas layer
d) Partial overhaul.
4.2.3.4 Pressure test standard
) The initial pressure test should be carried out according to the rated pressure; SY 6432-1999
b) When the BOP group is installed on the casing head for pressure test, the test pressure shall not exceed 70% of the casing's internal pressure resistance, and the test pressure of the molded BOP shall not exceed 50% of its rated pressure, and the test pressure of the gate BOP shall not exceed 70% of its rated pressure. 4.2.4 BOP activities
) The gate BOP is operated once a day;
6) The full seal is operated once after each drilling, or once per person: c) The annular BOP is operated once a week;
d) The choke manifold brush door, drill pipe cock, and drill pipe "internal BOP" are operated once a week. 4.2.5 Inspection and maintenance
Should be carried out according to the procedures provided by the supplier; the appearance inspection shall not be more than once a day. 4.3 Well control requirements
4.3.1 Well control system
The well control system established by the drilling and facility construction shall at least include the following: a) Certified well control operation;
b) Well control equipment management;
c) Application and approval for drilling oil and gas formations;
d) Well control operation drills;
r) Well control display observation;
f) Personnel on duty;
|) Well blowout accident report;
h) Well control meeting;
Job responsibilities.
4.3.2 Well control material preparation
Should comply with the provisions of 7.6 of SY 6307-1997. 4.4 Well control measures
4.4.1, Beach preparation before drilling oil and gas layer
4.4.1.1 The well control measures should be explained
4.4.1.2 The drilling and liquid dry, weighted materials, and weighted sales report reserves should meet the design requirements. 4.4,1.3 The post personnel are in place
4.4.1.4 The declaration is implemented and approved.
4.4.2 Well control operations after drilling oil and gas layer
4.4.2.1 Conduct formation pressure monitoring and
monitor the flow.
If the drilling speed suddenly increases, narrows, drowns, stops the drill, the gas measurement value is abnormal, the oil and gas is small, etc. are found during drilling, the drilling should be stopped for observation.
If overflow is found, the well shall be shut down; the pressure shall not exceed the specified value. 4.4.2.4
4.4.2.5 After the gas is raised, a short trip should be carried out before the drill is pulled out, and the gas shall be squeezed out at the specified speed after the drill is pulled out. 4.4.2.6
After the well is shut down due to overflow, it should be reported step by step13
SY 6432—1999
4.4.2.7 For oil and gas wells containing hydrogen sulfide, anti-hydrogen sulfide materials should be stored before opening the hydrogen sulfide formation, and the operating personnel should have preventive measures. 4.4.3
It should be carried out according to the operating procedures.
5 Downhole operations
5.1 Well control design
5.1.1 The approved construction modification plan should include well control design. 5.1.2 Work is not allowed to start without well control technical explanation before construction. 5.1.3 Well control devices, blowout prevention materials and tools should be prepared according to the construction design before construction. 5.2 Well control devices
5.2.1 Well control devices include: accumulator pump group, control console, blowout preventer group, well 11 valve group, well killing manifold, special tools, etc. 5.2.2 Well control devices should be inspected every year and obtain valid certificates1. 5.2.3 Accumulator group: The accumulator pump group should meet the requirements of SY5053.2. Control console: Each shallow-water oil downhole operation platform facility should be equipped with a control console according to the requirements of 7.4 of SY6307-1997. 5.2.4
5.2.5 BOP group:
5.2.5.1 Combination and selection:
a) The combination should include universal BOP, hydraulic double gate BOP. For dynamic gate BOP; after the joint, it should have semi-sealed and fully sealed functions.
b) The selection should meet the requirements of 6.2.1.5 in SY 6321-1997. 5.2.5.2 BOP should be assembled and pressure tested as required, and should meet the requirements of 6.2~6.5 in SY5053.1-92. After the test, the pressure test card ratio should be filled in.
5.2.5.3 When using the drilling platform and 1 device for downhole operations, the BOP should match the downhole operation string. 5.2.5.4 The management of the BOP should meet the requirements of 6.1~-6.6 in SY/T61201995. 5.2.5.5 For oil and gas containing hydrogen sulfide gas, the blowout preventer group used should be sulfur-proof type. 5.2.5.6 Inspection of blowout preventer:
a) After the blowout preventer is installed in the well, it should be opened and closed flexibly and reliably. It can be operated only after passing the pressure test, and the record should be filled in. b) The blowout preventer should be operated once per shift, and the full-sealed blowout preventer should be inspected after each arm column is raised. 5.2. Valve button: It should be equipped with casing four-way and oil pipe gate valve according to the construction design requirements, and pass the pressure test. 5.2.7 Well killing manifold:
5.2.7.1 The well killing manifold should not be less than the rated working pressure of the blowout preventer, and the tool should be of fire-proof type. When exploring and testing oil in shallow waters, it should meet the requirements of SY 6307-1997 7.5.1~7.5.3. 5.2.7.2 It is advisable to install a set of dynamic pressure well fluid injection equipment, and the pressure well fluid injection pipeline is connected to the well gate. 5.3 Well control requirements
5.3. Before downhole operations, the well manifold should be fixed and connected to the drill pump cabinet, and the drill pump group should be in good condition. 5.3.2 The pressure well fluid capacity should meet the design requirements, and the liquid reserve should not be less than 2 times the well volume. 5.3.3 When the construction cannot be continuous, the blowout preventer should be closed, the tubing gate valve should be installed and effectively fixed. 5.4 Well control measures
5.4.1 Perforation
5.4.1.1 For underwater well operation perforation, oil transmission perforation is preferred: if cable perforation is used, appropriate well killing fluid and a reliable blowout prevention device should be selected.
5.4.1.2 Before perforating, the casing, blowout preventer and tubing gate valve should be tested for pressure according to the design requirements. 5.41.3 After the perforating pipe is lowered, the valve should be installed and fixed to the back of the pipe, which is called the shooting ceremony. 5.4.1.4 Before lifting the perforating pipe string, the fluid should be circulated and observed to see if there are any abnormalities in the oil casing. Only after confirming that there are no abnormalities can the pipe string be lifted.
SY 6432—1999
5.4.1.5 When lifting the pipe string, the requirements of 6.2.2.1~6.2.2.4 in SY6321—1997 shall be followed. 5.4.1.6 When using cable shooting, the provisions of 5.1.3~5.1.5 in SY/T6120—1995 shall be followed. 5.4.2 Formation test
The performance inspection and pressure test of the test well device shall be carried out according to the provisions of SY/r5710. 5.4.2.2 The ground outlet shall use steel pipelines, pass the pressure test, and be effectively fixed. During the test, anti-blowout equipment should be prepared, the wellhead condition should be closely observed, and if signs of blowout are found, decisive measures should be taken according to the actual situation to prevent blowout: After the test, the well should be pressed according to the design requirements, and the liquid density at the inlet and outlet should be consistent. Only when there is no abnormality at the inlet, can the pipe column be lifted. 5.4.2.5 When lifting the pipe column, the requirements of 6.2.2.1~6.2.2.4 in SY 6321-1997 should be followed. 5.4.3 Repair and merging operations
5.4.3.1 Repair and merging operations The blowout prevention requirements should be implemented according to the requirements of SY6321--199716.2.2-6.2.6. 5.4.3.2 When drilling pipe is used for workover, a rotary valve with the rated working pressure of the blowout preventer shall be installed. 6 Oil (gas) production
6.1 Control design
6.1.1 Shallow sea oil (gas) wells shall be equipped with downhole safety valves and packers to seal the oil flow channels of the oil pipe and casing. 6.1.2 The completion engineering design shall be submitted to the superior department for approval before implementation. 6.2 Well control device
6.2.1 Device
Well control device includes: downhole safety valve, packer, exhaust valve, wellhead safety valve, Christmas tree, ground control panel, etc. 6.2.2 Downhole safety valve
6.2.2.1 The selection of downhole safety valve shall comply with the provisions of 6.1.1.2 and 6.1.1.3 in SY6321-1997. 6.2.2.2 The depth of the downhole safety valve shall be determined according to the provisions of 2.2c) of SYT4807-92, and wax deposition points shall be avoided. 6.2.2.3 Before the safety valve is lowered, an appearance inspection shall be carried out. The valve should not be deformed, the connecting thread is intact and has expansion thread, and there is no foreign matter in the valve:
6.2.2.4 Before the safety valve is used, an indoor switch test shall be carried out. After five switches, the opening and closing pressures of the inspected safety valve shall reach the specified values.
6.2.2.5 Before the safety valve is used, an indoor valve plate sealing test shall be carried out: a) Liquid sealing test. The test pressure is the rated working pressure, the test time is more than 30min, and the leakage volume does not exceed 10m!./mir to be qualified;
h) Gas sealing test. The test pressure is 1.4MPa, the test time is more than 30min, and the leakage volume does not exceed 18L/min to be qualified. 6.2.2.6 Before the safety valve is lowered, a hydraulic system sealing test should be conducted. The test pressure is the rated working pressure, and the pressure should be observed for at least 10 minutes. If the pressure drop does not exceed 5% of the test pressure after the pressure stabilizes, then observe for another 30 minutes. If the pressure does not drop, it is qualified. 6.2.2.7 During the installation process, each connection point on the hydraulic control pipeline should be pressure tested. The test pressure is the rated working pressure, and the pressure should be observed for at least 10 minutes. If the pressure drop does not exceed 5% of the test pressure after the pressure stabilizes, then observe for another 30 minutes. If the pressure does not drop, it is qualified. 6.2.2.8 The safety valve should always be in the open state during the lowering process, and the pressure in the control pipeline should be kept above the opening pressure of the safety valve to observe the working condition of the hydraulic control system. 6.2.2.9 After the wellhead is installed and before the packer is set, the pressure transmission system of the oil wellhead should be pressure tested. The test pressure is the rated working pressure, and the pressure should be observed for at least 10 minutes. If the pressure drop does not exceed 5% of the test pressure after the pressure stabilizes, then observe for another 30 minutes. If the pressure does not drop, it is qualified.
6.2.3 Packer
SY 6432—1999
6.2.3.1 The selection of packer should consider the technical parameters such as setting pressure, pressure difference between upper and lower parts of the seal, adaptability to environmental conditions, and unsealing force. 6.2.3.2 Before the packer is put into the well, an appearance inspection shall be carried out. The steel body, rubber cylinder and thread shall not be damaged or deformed. The number of shear nails for setting and releasing shall be correct.
6.2.3.3 Before the packer is used, a sealing test shall be carried out indoors. The test pressure shall be 2MPa lower than the starting pressure of the packer for setting. The test time shall be more than 10min. The pressure drop shall not exceed 15% of the test pressure for passing. 6.2.3.4 The packer shall be sealed according to the design requirements. The setting position shall avoid the casing coupling. The seal shall be inspected according to the design requirements. 6.2.4 Exhaust valve
6.2.4.1 When selecting an exhaust valve, the minimum opening pressure, rated working pressure, and environmental conditions shall be considered. 6.2.4.2 Before the exhaust valve is installed, an appearance inspection shall be carried out. The outer surface shall be free of vortex damage, the thread shall be intact, and the cone and the valve stem shall be firmly connected. 6.2.4.3 Before the exhaust valve is used, a valve reversal test shall be carried out. The test method shall be carried out according to 6.2.2.5. 6.2.4.4 The hydraulic control system sealing test should be carried out before the exhaust valve is used. The test pressure is the rated working pressure, and it should be observed for at least 10 minutes. If the pressure drop does not exceed 5% of the test pressure after the pressure stabilizes, it should be observed for another 30 minutes. If the pressure does not drop, it is qualified. 6.2.4.5 The exhaust valve should be closed during the seal inspection of the packer. 6.2.5 Wellhead safety valve
6.2.5.1 The valve rest part of the wellhead safety valve should have the same pressure rating, diameter, connection form and other working parameters and performance parameters as other manual gate valves of the Christmas tree. The selection of its control actuator should consider the following technical parameters: operation mode, operating pressure, adaptability to overflow, adaptability to environmental conditions, valve stem action distance, safety switch times, safety working life, closing speed, etc. 6.2.5.2 For self-flowing wells, electric pump wells, gas lift wells, and hydraulic pump wells, the wellhead safety valve should be installed at the second position above the Christmas tree; for ground-driven screw pump wells and rod pump wells, the wellhead safety valve should be installed at the position where the Christmas tree wing valve is connected to the oil pipeline.
6.2.5.3 The wellhead safety valve should be tested for opening and closing before use. After opening and closing 5 times, the opening pressure, closing pressure, and closing speed of the open safety valve under test should reach the specified values.
6.2.5.4 The wellhead safety valve should be tested for stability and sealing before use. The wellhead safety valve should be closed to release the pressure downstream of the wellhead safety valve. Under the condition of pressure upstream of the parallel safety valve, observe for more than 30 minutes. If the continuous liquid flow does not exceed 400ml.min or the gas flow does not exceed 0.4m/min, it is qualified.
6.2.6 Oil Tree
Requirements for oil tree shall comply with the provisions of 7.1 of SY6321-1997. 6.2.7 Ground Control Panel
6.2.7.1 For injection (gas) production wells equipped with downhole valves, exhaust valves and well safety valves, ground control panels should be installed for automatic control. bZxz.net
6.2.7.2 The ground control panel should be selected based on platform power conditions, installation location, number of controlled wells, operating media, environmental conditions and other factors. The main selection items should include: a) Material: should meet the requirements of strength, fatigue, corrosion resistance and ambient temperature; b) Control system: hydraulic or air pressure; c) Drive mode: manual, electric, pneumatic or pulsating; d) Working pressure: the rated working pressure and maximum working pressure of each component of the control system shall not be lower than the rated working pressure and maximum working pressure of the controlled safety valve or exhaust valve; e) Function selection; operation procedure; delay mechanism of wellhead safety valve, downhole safety valve and exhaust valve action procedure; h) Control distance; explosion-proof level of ground control panel; emergency closing mechanism; k) Temperature control circuit (fusible plug circuit); SY 6432--1999
1) For the ground excavation panel with automatic operation of energy storage device, the high pressure medium stored in the energy storage device shall ensure the energy reserve of more than 5 times of supplementary pressure:
m) Sensor: Analyze and determine the available sensors, including thermal sensors, pressure sensors and liquid level sensors. 6.2.7.3 The ground control panel shall be installed in the safe area of wide, bright and accessible areas. 6.2.74 For the oil production platform with remote control function, the control panel shall be connected with the automation system, which can timely monitor the pressure of the downhole safety system and quickly remotely close all the oil wells of the platform! 1 Safety valve, downhole safety exhaust: For the oil production platform without telemetry and remote control automation, the ground control panel shall install the emergency shut-off device at the entrance (airplane apron, emergency passage of lifeboat, ladder entrance) of the remote high-altitude field, marked with a red self-evident sign, to ensure that the oil and gas wells can be manually closed in case of emergency evacuation. 6.2.7.5 In Class 0 and Class 1 hazardous areas and other flammable and explosive areas of the platform, a temperature control circuit (fusible plug circuit) shall be installed, with a melting temperature of no more than 80°C and a shut-off reaction time of no more than 15s, to ensure that the oil and gas well can be automatically shut down in an emergency in the event of an accidental fire. 6.2.7.6 The upper and lower limits of the control pressure of the control panel shall be set according to the operating force range of the controlled safety valve. 6.2.7.7 Before connecting the safety valve, all hydraulic, gas or electric functions shall be tested according to the operating procedures. 6.3 Inspection
6.31 The downhole and wellhead safety valves shall be tested once every six months to ensure that they are always in normal working condition. 6.3.2 During normal production, the ground control panel shall be tested for function every six months to ensure that it is always in normal working condition. 6.3.3 Before the oil well is put into production or reopened after being shut down, the control pressure of the safety control system shall be checked to ensure that it is kept within the safe operating force range. The pressure of the hydraulic control system should be checked every time, and the inspection results should be recorded in the production team report. Any abnormal situation should be dealt with in a timely manner.
Water (gas) injection operation
7.1 Well control design
7.1.1 All water (gas) injection wells should be equipped with downhole safety valves and sealers. 7.1.2 The design of the water (gas) injection project should be submitted to the superior main arm department for approval before implementation. 7.2 Well control equipment
7.2.1 Well control equipment includes: downhole safety valves, washable seals, plate-mouth safety valves, mining trees, ground control discs, etc. 7.2.2 The requirements for well control equipment for water injection wells are the same as those in Chapter 6. 8 Emergency handling
When an emergency such as a blowout, pipeline leakage, fire, etc. endangers the safety of the platform or is damaged by force majeure, the on-site production arm management personnel should execute according to the emergency plan.7.1 For injection (gas) production wells equipped with downhole valves, exhaust valves and well safety valves, a ground control panel should be installed to automatically control them.
6.2.7.2 The ground control panel should be selected based on factors such as platform power conditions, installation location, number of controlled wells, operating media, and environmental conditions. The main selection items should include: a) Material: should meet the requirements of strength, fatigue, corrosion resistance and ambient temperature; b) Control system: hydraulic or air pressure; c) Drive mode: manual, electric, pneumatic or pulsating; d) Working pressure: the rated working pressure and maximum working pressure of each component of the control system shall not be lower than the rated working pressure and maximum working pressure of the controlled safety valve or exhaust valve; e) Function selection; operation procedure; delay mechanism of wellhead safety valve, downhole safety valve and exhaust valve action procedure; h) Control distance; explosion-proof level of ground control panel; emergency closing mechanism; k) Temperature control circuit (fusible plug circuit); SY 6432--1999
1) For the ground excavation panel with automatic operation of energy storage device, the high pressure medium stored in the energy storage device shall ensure the energy reserve of more than 5 times of supplementary pressure:
m) Sensor: Analyze and determine the available sensors, including thermal sensors, pressure sensors and liquid level sensors. 6.2.7.3 The ground control panel shall be installed in the safe area of wide, bright and accessible areas. 6.2.74 For the oil production platform with remote control function, the control panel shall be connected with the automation system, which can timely monitor the pressure of the downhole safety system and quickly remotely close all the oil wells of the platform! 1 Safety valve, downhole safety exhaust: For the oil production platform without telemetry and remote control automation, the ground control panel shall install the emergency shut-off device at the entrance (airplane apron, emergency passage of lifeboat, ladder entrance) of the remote high-altitude field, marked with a red self-evident sign, to ensure that the oil and gas wells can be manually closed in case of emergency evacuation. 6.2.7.5 In Class 0 and Class 1 hazardous areas and other flammable and explosive areas of the platform, a temperature control circuit (fusible plug circuit) shall be installed, with a melting temperature of no more than 80°C and a shut-off reaction time of no more than 15s, to ensure that the oil and gas well can be automatically shut down in an emergency in the event of an accidental fire. 6.2.7.6 The upper and lower limits of the control pressure of the control panel shall be set according to the operating force range of the controlled safety valve. 6.2.7.7 Before connecting the safety valve, all hydraulic, gas or electric functions shall be tested according to the operating procedures. 6.3 Inspection
6.31 The downhole and wellhead safety valves shall be tested once every six months to ensure that they are always in normal working condition. 6.3.2 During normal production, the ground control panel shall be tested for function every six months to ensure that it is always in normal working condition. 6.3.3 Before the oil well is put into production or reopened after being shut down, the control pressure of the safety control system shall be checked to ensure that it is kept within the safe operating force range. The pressure of the hydraulic control system should be checked every time, and the inspection results should be recorded in the production team report. Any abnormal situation should be dealt with in a timely manner.
Water (gas) injection operation
7.1 Well control design
7.1.1 All water (gas) injection wells should be equipped with downhole safety valves and sealers. 7.1.2 The design of the water (gas) injection project should be submitted to the superior main arm department for approval before implementation. 7.2 Well control equipment
7.2.1 Well control equipment includes: downhole safety valves, washable seals, plate-mouth safety valves, mining trees, ground control discs, etc. 7.2.2 The requirements for well control equipment for water injection wells are the same as those in Chapter 6. 8 Emergency handling
When an emergency such as a blowout, pipeline leakage, fire, etc. endangers the safety of the platform or is damaged by force majeure, the on-site production arm management personnel should execute according to the emergency plan.7.1 For injection (gas) production wells equipped with downhole valves, exhaust valves and well safety valves, a ground control panel should be installed to automatically control them.
6.2.7.2 The ground control panel should be selected based on factors such as platform power conditions, installation location, number of controlled wells, operating media, and environmental conditions. The main selection items should include: a) Material: should meet the requirements of strength, fatigue, corrosion resistance and ambient temperature; b) Control system: hydraulic or air pressure; c) Drive mode: manual, electric, pneumatic or pulsating; d) Working pressure: the rated working pressure and maximum working pressure of each component of the control system shall not be lower than the rated working pressure and maximum working pressure of the controlled safety valve or exhaust valve; e) Function selection; operation procedure; delay mechanism of wellhead safety valve, downhole safety valve and exhaust valve action procedure; h) Control distance; explosion-proof level of ground control panel; emergency closing mechanism; k) Temperature control circuit (fusible plug circuit); SY 6432--1999
1) For the ground excavation panel with automatic operation of energy storage device, the high pressure medium stored in the energy storage device shall ensure the energy reserve of more than 5 times of supplementary pressure:
m) Sensor: Analyze and determine the available sensors, including thermal sensors, pressure sensors and liquid level sensors. 6.2.7.3 The ground control panel shall be installed in the safe area of wide, bright and accessible areas. 6.2.74 For the oil production platform with remote control function, the control panel shall be connected with the automation system, which can timely monitor the pressure of the downhole safety system and quickly remotely close all the oil wells of the platform! 1 Safety valve, downhole safety exhaust: For the oil production platform without telemetry and remote control automation, the ground control panel shall install the emergency shut-off device at the entrance (airplane apron, emergency passage of lifeboat, ladder entrance) of the remote high-altitude field, marked with a red self-evident sign, to ensure that the oil and gas wells can be manually closed in case of emergency evacuation. 6.2.7.5 In Class 0 and Class 1 hazardous areas and other flammable and explosive areas of the platform, a temperature control circuit (fusible plug circuit) shall be installed, with a melting temperature of no more than 80°C and a shut-off reaction time of no more than 15s, to ensure that the oil and gas well can be automatically shut down in an emergency in the event of an accidental fire. 6.2.7.6 The upper and lower limits of the control pressure of the control panel shall be set according to the operating force range of the controlled safety valve. 6.2.7.7 Before connecting the safety valve, all hydraulic, gas or electric functions shall be tested according to the operating procedures. 6.3 Inspection
6.31 The downhole and wellhead safety valves shall be tested once every six months to ensure that they are always in normal working condition. 6.3.2 During normal production, the ground control panel shall be tested for function every six months to ensure that it is always in normal working condition. 6.3.3 Before the oil well is put into production or reopened after being shut down, the control pressure of the safety control system shall be checked to ensure that it is kept within the safe operating force range. The pressure of the hydraulic control system should be checked every time, and the inspection results should be recorded in the production team report. Any abnormal situation should be dealt with in a timely manner.
Water (gas) injection operation
7.1 Well control design
7.1.1 All water (gas) injection wells should be equipped with downhole safety valves and sealers. 7.1.2 The design of the water (gas) injection project should be submitted to the superior main arm department for approval before implementation. 7.2 Well control equipment
7.2.1 Well control equipment includes: downhole safety valves, washable seals, plate-mouth safety valves, mining trees, ground control discs, etc. 7.2.2 The requirements for well control equipment for water injection wells are the same as those in Chapter 6. 8 Emergency handling
When an emergency such as a blowout, pipeline leakage, fire, etc. endangers the safety of the platform or is damaged by force majeure, the on-site production arm management personnel should execute according to the emergency plan.
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