(a) Notification. You must:
(1) Notify the District Manager at least 72 hours before you commence initial production on a facility as required in §250.800(a)(2), in order for BSEE to conduct the preproduction inspection of the integrated safety system.
(2) Notify the District Manager upon commencement of production so that BSEE may conduct a complete inspection.
(3) Notify the District Manager and receive BSEE approval before you perform any subsea intervention that modifies the existing subsea infrastructure in a way that may affect the casing monitoring capabilities and testing frequencies specified in the table set forth in paragraph (c)(4) of this section.
(b) Testing methodologies. You must:
(1) Test safety valves and other equipment at the intervals specified in the tables set forth in paragraph (c) of this section or more frequently if operating conditions warrant; and
(2) Perform testing and inspections in accordance with API RP 14C, Appendix D (incorporated by reference as specified in §250.198), and the additional requirements specified in the tables of this section or as approved in the DWOP for your subsea system.
(c) Testing frequencies. You must:
(1) Comply with the following testing requirements for subsurface safety devices on dry tree wells:
| Item name | Testing frequency, allowable leakage rates, and other requirements |
|---|---|
| (i) Surface-controlled SSSVs (including devices installed in shut-in and injection wells) | Semi-annually, not to exceed 6 calendar months between tests. Also test in place when first installed or reinstalled. If the device does not operate properly, or if a liquid leakage rate > 400 cubic centimeters per minute or a gas leakage rate > 15 standard cubic feet per minute is observed, the device must be removed, repaired, and reinstalled or replaced. Testing must be according to ANSI/API RP 14B (incorporated by reference in §250.198) to ensure proper operation. |
| (ii) Subsurface-controlled SSSVs | Semi-annually, not to exceed 6 calendar months between tests for valves not installed in a landing nipple and 12 months for valves installed in a landing nipple. The valve must be removed, inspected, and repaired or adjusted, as necessary, and reinstalled or replaced. |
| (iii) Tubing plug | Semi-annually, not to exceed 6 calendar months between tests. Test by opening the well to possible flow. If a liquid leakage rate > 400 cubic centimeters per minute or a gas leakage rate > 15 standard cubic feet per minute is observed, the plug must be removed, repaired, and reinstalled or replaced. An additional tubing plug may be installed in lieu of removal. |
| (iv) Injection valves | Semi-annually, not to exceed 6 calendar months between tests. Test by opening the well to possible flow. If a liquid leakage rate > 400 cubic centimeters per minute or a gas leakage rate > 15 standard cubic feet per minute is observed, the valve must be removed, repaired and reinstalled or replaced. |
(2) Comply with the following testing requirements for surface valves:
| Item name | Testing frequency and requirements |
|---|---|
| (i) PSVs | Annually, not to exceed 12 calendar months between tests. Valve must either be bench-tested or equipped to permit testing with an external pressure source. Weighted disc vent valves used as PSVs on atmospheric tanks may be disassembled and inspected in lieu of function testing. The main valve piston must be lifted during this test. |
| (ii) Automatic inlet SDVs that are actuated by a sensor on a vessel or compressor | Once each calendar month, not to exceed 6 weeks between tests. |
| (iii) SDVs in liquid discharge lines and actuated by vessel low-level sensors | Once each calendar month, not to exceed 6 weeks between tests. |
| (iv) SSVs | Once each calendar month, not to exceed 6 weeks between tests. Valves must be tested for both operation and leakage. You must test according to API STD 6AV2 (incorporated by reference in §250.198). If an SSV does not operate properly or if any gas and/or liquid fluid flow is observed during the leakage test, the valve must be immediately repaired or replaced. |
| (v) Flowline FSVs | Once each calendar month, not to exceed 6 weeks between tests. All flowline FSVs must be tested, including those installed on a host facility in lieu of being installed at a satellite well. You must test flowline FSVs for leakage in accordance with the test procedure specified in API RP 14C (incorporated by reference as specified in §250.198). If leakage measured exceeds a liquid flow of 400 cubic centimeters per minute or a gas flow of 15 standard cubic feet per minute, the FSV must be repaired or replaced. |
(3) Comply with the following testing requirements for surface safety systems and devices:
| Item name | Testing frequency and requirements |
|---|---|
| (i) Pumps for firewater systems | Must be inspected and operated according to API RP 14G, Section 7.2 (incorporated by reference as specified in §250.198). |
| (ii) Fire- (flame, heat, or smoke) and gas detection systems | Must be tested for operation and recalibrated every 3 months, not to exceed 120 days between tests, provided that testing can be performed in a non-destructive manner. Open flame or devices operating at temperatures that could ignite a methane-air mixture must not be used. All combustible gas-detection systems must be calibrated every 3 months. |
| (iii) ESD systems | (A) Pneumatic based ESD systems must be tested for operation at least once each calendar month, not to exceed 6 weeks between tests. You must conduct the test by alternating ESD stations monthly to close at least one wellhead SSV and verify a surface-controlled SSSV closure for that well as indicated by control circuitry actuation. All stations must be checked for functionality at least once each calendar month, not to exceed 6 weeks between tests. No station may be reused until all stations have been tested. (B) Electronic based ESD systems must be tested for operation at least once every 3 calendar months, not to exceed 120 days between tests. The test must be conducted by alternating ESD stations to close at least one wellhead SSV and verify a surface-controlled SSSV closure for that well as indicated by control circuitry actuation. All stations must be checked for functionality at least once every 3 calendar months, not to exceed 120 days between checks. No station may be reused until all stations have been tested. (C) Electronic/pneumatic based ESD systems must be tested for operation at least once every 3 calendar months, not to exceed 120 days between tests. The test must be conducted by alternating ESD stations to close at least one wellhead SSV and verify a surface-controlled SSSV closure for that well as indicated by control circuitry actuation. All stations must be checked for functionality at least once every 3 calendar months, not to exceed 120 days between checks. No station may be reused until all stations have been used. |
| (iv) TSH devices | Must be tested for operation annually, not to exceed 12 calendar months between tests, excluding those addressed in paragraph (c)(3)(v) of this section and those that would be destroyed by testing. Those that could be destroyed by testing must be visually inspected and the circuit tested for operations at least once every 12 months. |
| (v) TSH shutdown controls installed on compressor installations that can be nondestructively tested | Must be tested every 6 months and repaired or replaced as necessary. |
| (vi) Burner safety low | Must be tested annually, not to exceed 12 calendar months between tests. |
| (vii) Flow safety low devices | Must be tested annually, not to exceed 12 calendar months between tests. |
| (viii) Flame, spark, and detonation arrestors | Must be visually inspected annually, not to exceed 12 calendar months between inspections. |
| (ix) Electronic pressure transmitters and level sensors: PSH and PSL; LSH and LSL | Must be tested at least once every 3 months, not to exceed 120 days between tests. |
| (x) Pneumatic/electronic switch PSH and PSL; pneumatic/electronic switch/electric analog with mechanical linkage LSH and LSL controls | Must be tested at least once each calendar month, not to exceed 6 weeks between tests. |
(4) Comply with the following testing requirements for subsurface safety devices and associated systems on subsea tree wells:
| Item name | Testing frequency, allowable leakage rates, and other requirements |
|---|---|
| (i) Surface-controlled SSSVs (including devices installed in shut-in and injection wells) | Tested semiannually, not to exceed 6 months between tests. If the device does not operate properly, or if a liquid leakage rate > 400 cubic centimeters per minute or a gas leakage rate > 15 standard cubic feet per minute is observed, the device must be removed, repaired, and reinstalled or replaced. Testing must be according to ANSI/API RP 14B (incorporated by reference in §250.198) to ensure proper operation, or as approved in your DWOP. |
| (ii) USVs | Tested at least once every 3 calendar months, not to exceed 120 days between tests. If the device does not function properly, or if a liquid leakage rate > 400 cubic centimeters per minute or a gas leakage rate > 15 standard cubic feet per minute is observed, the valve must be removed, repaired, and reinstalled or replaced. |
| (iii) BSDVs | Tested at least once each calendar month, not to exceed 6 weeks between tests. Valves must be tested for both operation and leakage. You must test according to API STD 6AV2 for SSVs (incorporated by reference in §250.198). If a BSDV does not operate properly or if any fluid flow is observed during the leakage test, the valve must be immediately repaired or replaced. |
| (iv) Electronic ESD logic | Tested at least once each calendar month, not to exceed 6 weeks between tests. |
| (v) Electronic ESD function | Tested at least once every 3 calendar months, not to exceed 120 days between tests. Shut-in at least one well during the ESD function test. If multiple wells are tied back to the same platform, a different well should be shut-in with each quarterly test. |
(d) Subsea wells.
(1) Any subsea well that is completed and disconnected from monitoring capability may not be disconnected for more than 24 months, unless authorized by BSEE.
(2) Any subsea well that is completed and disconnected from monitoring capability for more than 6 months must meet the following testing and other requirements:
(i) Each well must have 3 pressure barriers:
(A) A closed and tested surface-controlled SSSV,
(B) A closed and tested USV, and
(C) One additional closed and tested tree valve.
(ii) For new completed wells, prior to the rig leaving the well, the pressure barriers must be tested as follows:
(A) The surface-controlled SSSV must be tested for leakage in accordance with §250.828(c);
(B) The USV and other pressure barrier must be tested to confirm zero leakage rate.
(iii) A sealing pressure cap must be installed on the flowline connection hub until the flowline is installed and connected. The pressure cap must be designed to accommodate monitoring for pressure between the production wing valve and cap. The pressure cap must also be designed so that a remotely operated vehicle can bleed pressure off, monitor for buildup, and confirm barrier integrity.
(iv) Pressure monitoring at the sealing pressure cap on the flowline connection hub must be performed in each well at intervals not to exceed 12 months from the time of initial testing of the pressure barrier (prior to demobilizing the rig from the field).
(v) You must have a drilling vessel capable of intervention into the disconnected well in the field or readily accessible for use until the wells are brought on line.
[81 FR 60918, Sept. 7, 2016, as amended at 83 FR 49262, Sept. 28, 2018]
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