30 C.F.R. §§ 250.851–250.872

§250.851. Pressure vessels (including heat exchangers) and fired vessels.

30 C.F.R. § 250.851

(a)

Pressure vessels (including heat exchangers) and fired vessels supporting production operations must meet the requirements in the following table:

(b)

Operating pressure ranges. You must use pressure recording devices to establish the new operating pressure ranges of pressure vessels at any time that the normalized system pressure changes by 50 psig or 5 percent. Once system pressure has stabilized, pressure recording devices must be utilized to establish the new operating pressure ranges. The pressure recording devices must document the pressure range over time intervals that are no less than 4 hours and no more than 30 days long. You must maintain the pressure recording information you used to determine current operating pressure ranges at your field office nearest the OCS facility or at another location conveniently available to the District Manager for as long as the information is valid.

(c)

Pressure shut-in sensors must be set according to the following table (initial set points for pressure sensors must be set utilizing gauge readings and engineering design):

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 84 FR 24706, May 29, 2019; 91 FR 35354, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 84 FR 24706, May 29, 2019; 91 FR 35354, June 10, 2026]

§250.852. Flowlines/Headers.

30 C.F.R. § 250.852

(a)

You must—

(1)

Equip flowlines from wells with both PSH and PSL sensors. You must locate these sensors in accordance with section A.1 of APR Recommended Practice 14 C (incorporated by reference, see § 250.198).

(2)

Use pressure recording devices to establish the new operating pressure ranges of flowlines at any time when the normalized system pressure changes by 50 psig or 5 percent, whichever is higher. The pressure recording devices must document the pressure range over time intervals that are no less than 4 hours and no more than 30 days long.

(3)

Maintain the most recent pressure recording information you used to determine operating pressure ranges at your field office nearest the OCS facility or at another location conveniently available to the District Manager for as long as the information is valid.

(b)

Flowline shut-in sensors must meet the requirements in the following table (initial set points for pressure sensors must be set using gauge readings and engineering design):

(c)

If a well flows directly to a pipeline before separation, the flowline and valves from the well located upstream of and including the header inlet valve(s) must have a working pressure equal to or greater than the maximum shut-in pressure of the well unless the flowline is protected by one of the following:

(1)

A relief valve which vents into the platform flare scrubber or some other location approved by the District Manager. You must design the platform flare scrubber to handle, without liquid-hydrocarbon carryover to the flare, the maximum-anticipated flow of hydrocarbons that may be relieved to the vessel; or

(2)

Two SSVs with independent PSH sensors connected to separate relays and sensing points and installed with adequate volume upstream of any block valve to allow sufficient time for the SSVs to close before exceeding the maximum allowable working pressure. Each independent PSH sensor must close both SSVs along with any associated flowline PSL sensor. If the maximum shut-in pressure of a dry tree satellite well(s) is greater than 1 1/2 times the maximum allowable pressure of the pipeline, a pressure safety valve (PSV) of sufficient size and relief capacity to protect against any SSV leakage or fluid hammer effect may be required by the District Manager. The PSV must be installed upstream of the host platform boarding valve and vent into the platform flare scrubber or some other location approved by the District Manager.

(d)

If a well flows directly to the pipeline from a header without prior separation, the header, the header inlet valves, and pipeline isolation valve must have a working pressure equal to or greater than the maximum shut-in pressure of the well unless the header is protected by the safety devices as outlined in paragraph (c) of this section.

(e)

If you are installing flowlines constructed of unbonded flexible pipe on a floating platform, you must:

(1)

Review the manufacturer's Design Methodology Verification Report and the independent verification agent's (IVA) certificate for the design methodology contained in that report to ensure that the manufacturer has complied with the requirements of API Specification 17J (incorporated by reference, see § 250.198);

(2)

Determine that the unbonded flexible pipe is suitable for its intended purpose;

(3)

Submit to the District Manager the manufacturer's design specifications for the unbonded flexible pipe; and

(4)

Submit to the District Manager a statement certifying that the pipe is suitable for its intended use and that the manufacturer has complied with the IVA requirements of API Specification 17J (incorporated by reference, see § 250.198).

(f)

Automatic pressure or flow regulating choking devices must not prevent the normal functionality of the process safety system that includes, but is not limited to, the flowline pressure safety devices and the SSV.

(g)

You may install a single flow safety valve (FSV) on the platform to protect multiple subsea pipelines or wells that tie into a single pipeline riser provided that you install an FSV for each riser on the platform and test it in accordance with the criteria prescribed in § 250.880(c)(2)(v).

(h)

You may install a single PSHL sensor on the platform to protect multiple subsea pipelines that tie into a single pipeline riser provided that you install a PSHL sensor for each riser on the platform and locate it upstream of the BSDV.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018; 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018; 91 FR 35355, June 10, 2026]

§250.853. Safety sensors.

30 C.F.R. § 250.853

You must ensure that:

(a)

All shutdown devices, valves, and pressure sensors function in a manual reset mode;

(b)

Sensors with integral automatic reset are equipped with an appropriate device to override the automatic reset mode;

(c)

All pressure sensors are equipped to permit testing with an external pressure source; and

(d)

All level sensors are equipped to permit testing through an external bridle on all new vessel installations where possible, depending on the type of vessel for which the level sensor is used.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018]

§250.854. Floating production units equipped with turrets and turret-mounted systems.

30 C.F.R. § 250.854

(a)

For floating production units equipped with an auto slew system, you must integrate the auto slew control system with your process safety system allowing for automatic shut-in of the production process, including the sources (subsea wells, subsea pumps, etc.) and releasing of the buoy. Your safety system must immediately initiate a process system shut-in according to §§ 250.838 and 250.839 and release the buoy to prevent hydrocarbon discharge and damage to the subsea infrastructure when the following are encountered:

(1)

Your buoy is clamped,

(2)

Your auto slew mode is activated, and

(3)

You encounter a ship heading/position failure or an exceedance of the rotational tolerances of the clamped buoy.

(b)

For floating production units equipped with swivel stack arrangements, you must equip the portion of the swivel stack containing hydrocarbons with a leak detection system. Your leak detection system must be tied into your production process surface safety system allowing for automatic shut-in of the system. Upon seal system failure and detection of a hydrocarbon leak, your surface safety system must immediately initiate a process system shut-in according to §§ 250.838 and 250.839.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.855. Emergency shutdown (ESD) system.

30 C.F.R. § 250.855

The ESD system must conform to the requirements of Appendix C, section C1, of API Recommended Practice 14C (incorporated by reference, see § 250.198), and the following:

(a)

The manually operated ESD valve(s) must be quick-opening and non-restricted to enable the rapid actuation of the shutdown system. Electronic ESD stations must be wired as de-energize to trip circuits or as supervised circuits. Because of the key role of the ESD system in the platform safety system, all ESD components must be of high quality and corrosion resistant and stations must be uniquely identified. Only ESD stations at the boat landing may utilize a loop of breakable synthetic tubing in lieu of a valve or electric switch. This breakable loop is not required to be physically located on the boat landing, but must be accessible from a vessel adjacent to or attached to the facility.

(b)

You must maintain a schematic of the ESD that indicates the control functions of all safety devices for the platforms on the platform, at your field office nearest the OCS facility, or at another location conveniently available to the District Manager, for the life of the facility.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

§250.856. Engines.

30 C.F.R. § 250.856

(a)

Engine exhaust. You must equip all engine exhausts to comply with the insulation and personnel protection requirements of API Recommended Practice 14C, section 4.2 (incorporated by reference, see § 250.198). You must equip exhaust piping from diesel engines with spark arresters.

(b)

Diesel engine air intake. You must equip diesel engine air intakes with a device to shut down the diesel engine in the event of runaway (i.e., overspeed). You must equip diesel engines that are continuously attended with either remotely operated manual or automatic shutdown devices. You must equip diesel engines that are not continuously attended with automatic shutdown devices. The following diesel engines do not require a shutdown device: Engines for fire water pumps; engines on emergency generators; engines that power BOP accumulator systems; engines that power air supply for confined entry personnel; temporary equipment on non-producing platforms; booster engines whose purpose is to start larger engines; and engines that power portable single cylinder rig washers.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

§250.857. Glycol dehydration units.

30 C.F.R. § 250.857

(a)

You must install a pressure relief system or an adequate vent on the glycol regenerator (reboiler) to prevent over pressurization. The discharge of the relief valve must be vented in a nonhazardous manner.

(b)

You must install the FSV on the dry glycol inlet to the glycol contact tower as near as practical to the glycol contact tower.

(c)

You must install the shutdown valve (SDV) on the wet glycol outlet from the glycol contact tower as near as practical to the glycol contact tower.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.858. Gas compressors.

30 C.F.R. § 250.858

(a)

You must equip compressor installations with the following protective equipment as required in API Recommended Practice 14C, sections A.4 and A.8 (incorporated by reference, see § 250.198).

(1)

A pressure safety high (PSH) sensor, a pressure safety low (PSL) sensor, a pressure safety valve (PSV), a level safety high (LSH) sensor, and a level safety low (LSL) sensor to protect each interstage and suction scrubber.

(2)

A temperature safety high (TSH) sensor in the discharge piping of each compressor cylinder or case discharge.

(3)

You must design the PSH and PSL sensors and LSH controls protecting compressor suction and interstage scrubbers to actuate automatic SDVs located in each compressor suction and fuel gas line so that the compressor unit and the associated vessels can be isolated from all input sources. All automatic SDVs installed in compressor suction and fuel gas piping must also be actuated by the shutdown of the prime mover. Unless otherwise approved by the District Manager, gas-well gas affected by the closure of the automatic SDV on the suction side of a compressor must be diverted to the pipeline, diverted to a flare or vent in accordance with §§ 250.1160 or 250.1161, or shut-in at the wellhead.

(4)

You must install a blowdown valve on the discharge line of all compressor installations that are 1,000 horsepower (746 kilowatts) or greater.

(b)

Once system pressure has stabilized, you must use pressure recording devices to establish the new operating pressure ranges for compressor discharge sensors whenever the normalized system pressure changes by 50 psig or 5 percent, whichever is higher. The pressure recording devices must document the pressure range over time intervals that are no less than 4 hours and no more than 30 days long. You must maintain the most recent pressure recording information that you used to determine operating pressure ranges at your field office nearest the OCS facility or at another location conveniently available to the District Manager.

(c)

Pressure shut-in sensors must be set according to the following table (initial set points for pressure sensors must be set utilizing gauge readings and engineering design):

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

§250.859. Firefighting systems.

30 C.F.R. § 250.859

(a)

On fixed facilities, to protect all areas where production-handling equipment is located, you must install firefighting systems that meet the requirements of this paragraph. You must install a firewater system consisting of rigid pipe with fire hose stations and/or fixed firewater monitors to protect all areas where production-handling equipment is located. Your firewater system must include installation of a fixed water spray system in enclosed well-bay areas where hydrocarbon vapors may accumulate.

(1)

Your firewater system must conform to API Recommended Practice 14G (incorporated by reference, see § 250.198).

(2)

Fuel or power for firewater pump drivers must be available for at least 30 minutes of run time during a platform shut-in. If necessary, you must install an alternate fuel or power supply to provide for this pump operating time unless the District Manager has approved an alternate firefighting system. In addition:

(i)

As of September 7, 2017, you must have equipped all new firewater pump drivers with automatic starting capabilities upon activation of the ESD, fusible loop, or other fire detection system.

(ii)

For electric-driven firewater pump drivers, to provide for a potential loss of primary power, you must install an automatic transfer switch to cross over to an emergency power source in order to maintain at least 30 minutes of run time. The emergency power source must be reliable and have adequate capacity to carry the locked-rotor currents of the fire pump motor and accessory equipment.

(iii)

You must route power cables or conduits with wires installed between the fire water pump drivers and the automatic transfer switch away from hazardous-classified locations that can cause flame impingement. Power cables or conduits with wires that connect to the fire water pump drivers must be capable of maintaining circuit integrity for not less than 30 minutes of flame impingement.

(3)

You must post, in a prominent place on the facility, a diagram of the firefighting system showing the location of all firefighting equipment.

(4)

For operations in subfreezing climates, you must furnish evidence to the District Manager that the firefighting system is suitable for those conditions.

(5)

You must obtain approval from the District Manager before installing any firefighting system.

(6)

All firefighting equipment located on a facility must be in good working order whether approved as the primary, secondary, or ancillary firefighting system.

(b)

On floating facilities, to protect all areas where production-handling equipment is located, you must install a firewater system consisting of rigid pipe with fire hose stations and/or fixed firewater monitors. You must install a fixed water spray system in enclosed well-bay areas where hydrocarbon vapors may accumulate. Your firewater system must conform to the USCG requirements for firefighting systems on floating facilities.

(c)

Except as provided in paragraph (c)(1) and (2) of this section, on fixed and floating facilities, if you are required to maintain a firewater system and the system becomes inoperable, you must shut-in your production operations while making the necessary repairs. For fixed facilities only, you may continue your production operations on a temporary basis while you make the necessary repairs, provided that:

(1)

You request that the appropriate District Manager approve the use of a chemical firefighting system on a temporary basis (for a period up to 7 days) while you make the necessary repairs;

(2)

If you are unable to complete repairs during the approved time period because of circumstances beyond your control, the District Manager may grant multiple extensions to your previously approved request to use a chemical firefighting system for periods up to 7 days each.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

§250.860. Chemical firefighting system.

30 C.F.R. § 250.860

For fixed platforms:

(a)

On minor unmanned platforms, you may use a U.S. Coast Guard type and size rating “B-II” portable dry chemical unit (with a minimum UL Rating (US) of 60-B:C) or a 30-pound portable dry chemical unit, in lieu of a water system, as long as you ensure that the unit is available on the platform when personnel are on board.

(1)

A minor platform is a structure with zero to five completions and no more than one item of production processing equipment.

(2)

An unmanned platform is one that is not attended 24 hours a day or one on which personnel are not quartered overnight.

(b)

On major platforms and minor manned platforms, you may use a firefighting system using chemicals-only in lieu of a water-based system if the District Manager determines that the use of a chemical system provides equivalent fire-protection control and would not increase the risk to human safety.

(1)

A major platform is a structure with either six or more completions or zero to five completions with more than one item of production processing equipment.

(2)

A minor platform is a structure with zero to five completions and no more than one item of production processing equipment.

(3)

A manned platform is one that is attended 24 hours a day or one on which personnel are quartered overnight.

(c)

On major platforms and minor manned platforms, to obtain approval to use a chemical-only fire prevention and control system in lieu of a water system under paragraph (b) of this section, you must submit to the District Manager:

(1)

A justification for asserting that the use of a chemical system provides equivalent fire-protection control. The justification must address fire prevention, fire protection, fire control, and firefighting on the platform; and

(2)

A risk assessment demonstrating that a chemical-only system would not increase the risk to human safety. You must provide the following and any other important information in your risk assessment:

(d)

On major or minor platforms, if BSEE has approved your request to use a chemical-only fire suppressant system in lieu of a water system under paragraphs (b) and (c) of this section, and if you make an insignificant change to your platform subsequent to that approval, you must document the change and maintain the documentation for the life of the facility at either the facility or nearest field office for BSEE review and/or inspection. Do not submit this documentation to the District Manager. However, if you make a significant change to your platform (e.g., placing a storage vessel with a capacity of 100 barrels or more on the facility, adding production equipment), or if you plan to man an unmanned platform temporarily, you must submit a new request for approval, including an updated risk assessment if previously required, to the appropriate District Manager. You must maintain, for the life of the facility, the most recent documentation that you submitted to BSEE at the facility or nearest field office.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.861. Foam firefighting systems.

30 C.F.R. § 250.861

When you install foam firefighting systems as part of a firefighting system that protects production handling areas, you must:

(a)

Annually conduct an inspection of the foam concentrates and their tanks or storage containers for evidence of excessive sludging or deterioration;

(b)

Annually send samples of the foam concentrate to the manufacturer or authorized representative for quality condition testing. You must have the sample tested to determine the specific gravity, pH, percentage of water dilution, and solid content. Based on these results, the foam must be certified by an authorized representative of the manufacturer as suitable firefighting foam consistent with the original manufacturer's specifications. The certification document must be readily accessible for field inspection. In lieu of sampling and certification, you may choose to replace the total inventory of foam with suitable new stock;

(c)

Ensure that the quantity of concentrate meets design requirements, and that tanks or containers are kept full, with space allowed for expansion.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.862. Fire and gas-detection systems.

30 C.F.R. § 250.862

For production processing areas only:

(a)

You must install fire (flame, heat, or smoke) sensors in all enclosed classified areas. You must install gas sensors in all inadequately ventilated, enclosed classified areas.

(1)

Adequate ventilation is defined as ventilation that is sufficient to prevent accumulation of significant quantities of vapor-air mixture in concentrations over 25 percent of the lower explosive limit. An acceptable method of providing adequate ventilation is one that provides a change of air volume each 5 minutes or 1 cubic foot of air-volume flow per minute per square foot of solid floor area, whichever is greater.

(2)

Enclosed areas (e.g., buildings, living quarters, or doghouses) are defined as those areas confined on more than 4 of their 6 possible sides by walls, floors, or ceilings more restrictive to air flow than grating or fixed open louvers and of sufficient size to allow entry of personnel.

(3)

A classified area is any area classified Class I, Group D, Division 1 or 2, following the guidelines of API Recommended Practice 500 (incorporated by reference, see § 250.198), or any area classified Class I, Zone 0, Zone 1, or Zone 2, following the guidelines of API Recommended Practice 505 (incorporated by reference, see § 250.198).

(b)

All detection systems must be capable of continuous monitoring. Fire-detection systems and portions of combustible gas-detection systems related to the higher gas-concentration levels must be of the manual-reset type. Combustible gas-detection systems related to the lower gas-concentration level may be of the automatic-reset type.

(c)

A fuel-gas odorant or an automatic gas-detection and alarm system is required in enclosed, continuously manned areas of the facility which are provided with fuel gas. A gas detection system is not required for living quarters and doghouses that do not contain a gas source and that are not located in a classified area.

(d)

The District Manager may require the installation and maintenance of a gas detector or alarm in any potentially hazardous area.

(e)

Fire- and gas-detection systems must be an approved type, and designed and installed in accordance with API Recommended Practice 14C, API Recommended Practice 14G, API Recommended Practice 14F, API Recommended Practice 14FZ, API Recommended Practice 500, and API Recommended Practice 505 (all incorporated by reference, see § 250.198), provided that, if compliance with any provision of those standards would be in conflict with applicable regulations of the U.S. Coast Guard, compliance with the U.S. Coast Guard regulations controls.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

§250.863. Electrical equipment.

30 C.F.R. § 250.863

You must design, install, and maintain electrical equipment and systems in accordance with the requirements in § 250.114.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.864. Erosion.

30 C.F.R. § 250.864

You must have a program of erosion control in effect for wells or fields that have a history of sand production. The erosion-control program may include sand probes, X-ray, ultrasonic, or other satisfactory monitoring methods. You must maintain records for each lease that indicate the wells that have erosion-control programs in effect. You must also maintain the results of the programs for at least 2 years and make them available to BSEE upon request.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.865. Surface pumps.

30 C.F.R. § 250.865

(a)

You must equip pump installations with the protective equipment required in API Recommended Practice 14C, Appendix A—A.7, Pumps (incorporated by reference, see § 250.198).

(b)

You must use pressure recording devices to establish the new operating pressure ranges for pump discharge sensors at any time when the normalized system pressure changes by 50 psig or 5 percent, whichever is higher. Once system pressure has stabilized, pressure recording devices must be utilized to establish the new operating pressure ranges. The pressure recording devices must document the pressure range over time intervals that are no less than 4 hours and no more than 30 days long. You must only maintain the most recent pressure recording information that you used to determine operating pressure ranges at your field office nearest the OCS facility or at another location conveniently available to the District Manager.

(c)

Pressure shut-in sensors must be set according to the following table (initial set points for pressure sensors must be set utilizing gauge readings and engineering design):

(d)

The PSL must be placed into service when the pump discharge pressure has risen above the PSL sensing point, or within 45 seconds of the pump coming into service, whichever is sooner.

(e)

You may exclude the PSH and PSL sensors on small, low-volume pumps such as chemical injection-type pumps. This is acceptable if such a pump is used as a sump pump or transfer pump, has a discharge rating of less than 1/2 gallon per minute (gpm), discharges into piping that is 1 inch or less in diameter, and terminates in piping that is 2 inches or larger in diameter.

(f)

You must install a TSE in the immediate vicinity of all pumps in hydrocarbon service or those powered by platform fuel gas.

(g)

The pump maximum discharge pressure must be determined using the maximum possible suction pressure and the maximum power output of the driver as appropriate for the pump type and service.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

§250.866. Personnel safety equipment.

30 C.F.R. § 250.866

You must maintain all personnel safety equipment located on a facility, whether required or not, in good working condition.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.867. Temporary quarters and temporary equipment.

30 C.F.R. § 250.867

(a)

You must equip temporary quarters with all safety devices required by API Recommended Practice 14C, Appendix C (incorporated by reference, see § 250.198). The District Manager must approve the safety system/safety devices associated with the temporary quarters prior to installation.

(b)

The District Manager may require you to install a temporary firewater system for temporary quarters in production processing areas or other classified areas.

(c)

Temporary equipment associated with the production process system, including equipment used for well testing and/or well clean-up, must be approved by the District Manager.

(d)

The District Manager must approve temporary generators that would require a change to the electrical one-line diagram in § 250.842(a).

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018; 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018; 91 FR 35355, June 10, 2026]

§250.868. Non-metallic piping.

30 C.F.R. § 250.868

On fixed OCS facilities, you may use non-metallic piping (such as that made from polyvinyl chloride, chlorinated polyvinyl chloride, and reinforced fiberglass) only in accordance with the requirements of § 250.841(b).

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.869. General platform operations.

30 C.F.R. § 250.869

(a)

Surface or subsurface safety devices must not be bypassed or blocked out of service unless they are temporarily out of service for startup, maintenance, or testing. You may take only the minimum number of safety devices out of service. Personnel must monitor the bypassed or blocked-out functions until the safety devices are placed back in service. Any surface or subsurface safety device which is temporarily out of service must be flagged. A designated visual indicator must be used to identify the bypassed safety device. You must follow the monitoring procedures as follows:

(1)

If you are using a non-computer-based system, meaning your safety system operates primarily with pneumatic supply or non-programmable electrical systems, you must monitor bypassed safety devices by positioning monitoring personnel at either the control panel for the bypassed safety device, or at the bypassed safety device, or at the component that the bypassed safety device would be monitoring when in service. You must also ensure that monitoring personnel are able to view all relevant essential operating conditions until all bypassed safety devices are placed back in service and are able to initiate shut-in action in the event of an abnormal condition.

(2)

If you are using a computer-based technology system, meaning a computer-controlled electronic safety system such as supervisory control and data acquisition and remote terminal units, you must monitor bypassed safety devices by maintaining instantaneous communications at all times among remote monitoring personnel and the personnel performing maintenance, testing, or startup. Until all bypassed safety devices are placed back in service, you must also position monitoring personnel at a designated control station that is capable of the following:

(i)

Displaying all relevant essential operating conditions that affect the bypassed safety device, well, pipeline, and process component. If electronic display of all relevant essential conditions is not possible, you must have field personnel monitoring the level gauges (sight glass) and pressure gauges in order to know the current operating conditions. You must be in communication with all field personnel monitoring the gauges;

(ii)

Controlling the production process equipment and the entire safety system;

(iii)

Displaying a visual indicator when safety devices are placed in the bypassed mode; and

(iv)

Upon command, overriding the bypassed safety device and initiating shut-in action in the event of an abnormal condition.

(3)

You must not bypass for startup any element of the emergency support system or other support system required by API Recommended Practice 14C, Appendix C (incorporated by reference, see § 250.198) without first receiving BSEE approval to depart from this operating procedure. These systems include, but are not limited to:

(i)

The ESD system to provide a method to manually initiate platform shutdown by personnel observing abnormal conditions or undesirable events. You do not have to receive approval from the District Manager for manual reset and/or initial charging of the system;

(ii)

The fire loop system to sense the heat of a fire and initiate platform shutdown, and other fire detection devices (flame, thermal, and smoke) that are used to enhance fire detection capability. You do not have to receive approval from the District Manager for manual reset and/or initial charging of the system;

(iii)

The combustible gas detection system to sense the presence of hydrocarbons and initiate alarms and platform shutdown before gas concentrations reach the lower explosive limit;

(iv)

Adequate ventilation;

(v)

The containment system to collect escaped liquid hydrocarbons and initiate platform shutdown;

(vi)

Subsurface safety valves, including those that are self-actuated (subsurface-controlled SSSVs) or those that are activated by an ESD system and/or a fire loop (surface-controlled SSSV). You do not have to receive approval from the District Manager for routine operations in accordance with § 250.817;

(vii)

The pneumatic supply system; and

(viii)

The system for discharging gas to the atmosphere.

(4)

In instances where components of the ESD, as listed in paragraph (a)(3) of this section, are bypassed for maintenance, precautions must be taken to provide the equivalent level of protection that existed prior to the bypass.

(b)

When wells are disconnected from producing facilities and blind flanged, or equipped with a tubing plug, or the master valves have been locked closed, you are not required to comply with the provisions of API Recommended Practice 14C (incorporated by reference, see § 250.198) or this regulation concerning the following:

(1)

Automatic fail-close SSVs on wellhead assemblies, and

(2)

The PSH and PSL sensors in flowlines from wells.

(c)

When pressure or atmospheric vessels are isolated from production facilities (e.g., inlet valve locked closed or inlet blind-flanged) and are to remain isolated for an extended period of time, safety device testing in accordance with API Recommended Practice 14C (incorporated by reference, see § 250.198), or this subpart is not required, with the exception of the PSV, unless the vessel is open to the atmosphere.

(d)

All open-ended lines connected to producing facilities and wells must be plugged or blind-flanged, except those lines designed to be open-ended such as flare or vent lines.

(e)

On all new production safety system installations, component process control devices and component safety devices must not be installed utilizing the same sensing points.

(f)

All pneumatic control panels and computer based control stations must be labeled according to API RP 14C nomenclature.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 91 FR 35355, June 10, 2026]

§250.870. Time delays on pressure safety low (PSL) sensors.

30 C.F.R. § 250.870

(a)

You may apply industry standard Class B, Class C, or Class B/C logic to applicable PSL sensors installed on process equipment. If the device may be bypassed for greater than 45 seconds, you must monitor the bypassed devices in accordance with § 250.869(a). You must document on your field test records any use of a PSL sensor with a time delay greater than 45 seconds. For purposes of this section, PSL sensors are categorized as follows:

(1)

Class B safety devices have logic that allows for the PSL sensors to be bypassed for a fixed time period (typically less than 15 seconds, but not more than 45 seconds). Examples include sensors used in conjunction with the design of pump and compressor panels such as PSL sensors, lubricator no-flows, and high-water jacket temperature shutdowns.

(2)

Class C safety devices have logic that allows for the PSL sensors to be bypassed until the component comes into full service (i.e., the time at which the startup pressure equals or exceeds the set pressure of the PSL sensor, the system reaches a stabilized pressure, and the PSL sensor clears). If a Class C safety device is bypassed, you must monitor the device until it is in full service.

(3)

Class B/C safety devices have logic that allows for the PSL sensors to incorporate a combination of Class B and Class C circuitry. These devices are used to ensure that the PSL sensors are not unnecessarily bypassed during startup and idle operations, (e.g., Class B/C bypass circuitry activates when a pump is shut down during normal operations). The PSL sensor remains bypassed until the pump's start circuitry is activated and either:

(i)

The Class B timer expires no later than 45 seconds from start activation, or

(ii)

The Class C bypass is initiated until the pump builds up pressure above the PSL sensor set point and the PSL sensor comes into full service.

(b)

If you do not install time delay circuitry that bypasses activation of PSL sensor shutdown logic for a specified time period on process and product transport equipment during startup and idle operations, you must manually bypass (pin out or disengage) the PSL sensor, with a time delay not to exceed 45 seconds.

Notes, amendments, and revision history

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[81 FR 61918, Sept. 7, 2016, as amended at 83 FR 49259, Sept. 28, 2018]

§250.871. Welding and burning practices and procedures.

30 C.F.R. § 250.871

All welding, burning, and hot-tapping activities must be conducted according to the specific requirements in § 250.113.

Notes, amendments, and revision history

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

§250.872. Atmospheric vessels.

30 C.F.R. § 250.872

(a)

You must equip atmospheric vessels used to process and/or store liquid hydrocarbons or other Class I liquids as described in API Recommended Practice 500 or API Recommended Practice 505 (both incorporated by reference, see § 250.198) with protective equipment identified in API Recommended Practice 14C, section A.5 (incorporated by reference, see § 250.198). Transport tanks approved by the U.S. Department of Transportation, that are sealed and not connected via interconnected piping to the production process train and that are used only for storage of refined liquid hydrocarbons or Class I liquids, are not required to be equipped with the protective equipment identified in API Recommended Practice 14C, section A.5. The atmospheric vessels connected to the process system that contains a Class I liquid and the associated pumps must be reflected on the design documents listed in § 250.842(a)(1) through (4) and (b)(3).

(b)

You must ensure that all atmospheric vessels are designed and maintained to ensure the proper working conditions for LSH sensors. The LSH sensor bridle must be designed to prevent different density fluids from impacting sensor functionality.

(c)

You must ensure that all atmospheric vessels are designed, installed, and maintained to prevent pollution, including the displacement of oil out of an overboard water outlet, as required by § 250.300(b)(3) and (4).

Notes, amendments, and revision history

Amendments

[83 FR 49259, Sept. 28, 2018, as amended at 91 FR 35355, June 10, 2026]

Source

Source: 81 FR 61918, Sept. 7, 2016, unless otherwise noted.

Authority

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.

Source

Source: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

Amendments

[83 FR 49259, Sept. 28, 2018, as amended at 91 FR 35355, June 10, 2026]