US Codex
C.F.R.
Browse by date

View an earlier version

Latest
Current
Browse all versions by date
Notes

30 C.F.R. §§ 250.1000–250.1008

9 sections in range

§250.1000. General requirements.

30 C.F.R. § 250.1000

(a)
Pipelines and associated valves, flanges, and fittings shall be designed, installed, operated, maintained, and abandoned to provide safe and pollution-free transportation of fluids in a manner which does not unduly interfere with other uses in the Outer Continental Shelf (OCS).
(b)
An application must be accompanied by payment of the service fee listed in § 250.125 and submitted to the Regional Supervisor and approval obtained before:
(1)
Installation, modification, or abandonment of a lease term pipeline;
(2)
Installation or modification of a right-of-way (other than lease term) pipeline; or
(3)
Modification or relinquishment of a pipeline right-of way.
(c)
(1)
Department of the Interior (DOI) pipelines, as defined in § 250.1001, must meet the requirements in §§ 250.1000 through 250.1008.
(2)
A pipeline right-of-way grant holder must identify in writing to the Regional Supervisor the operator of any pipeline located on its right-of-way, if the operator is different from the right-of-way grant holder.
(3)
A producing operator must identify for its own records, on all existing pipelines located on its lease or right-of-way, the specific points at which operating responsibility transfers to a transporting operator.
(i)
Each producing operator must, if practical, durably mark all of its above-water transfer points as of the date a pipeline begins service.
(ii)
If it is not practical to durably mark a transfer point, and the transfer point is located above water, then the operator must identify the transfer point on a schematic located on the facility.
(iii)
If a transfer point is located below water, then the operator must identify the transfer point on a schematic and provide the schematic to BSEE upon request.
(iv)
If adjoining producing and transporting operators cannot agree on a transfer point, the BSEE Regional Supervisor and the appropriate Department of Transportation (DOT) pipeline official may jointly determine the transfer point.
(4)
The transfer point serves as a regulatory boundary. An operator may request that the BSEE Regional Supervisor grant an exception to this requirement for an individual facility or area. The Regional Supervisor, in consultation with the appropriate DOT pipeline official and affected parties, may grant the request.
(5)
Pipeline segments designed, constructed, maintained, and operated under DOT regulations but transferring to DOI regulation as of October 16, 1998, may continue to operate under DOT design and construction requirements until significant modifications or repairs are made to those segments. After October 16, 1998, BSEE operational and maintenance requirements will apply to those segments.
(6)
Any producer operating a pipeline that crosses into State waters without first connecting to a transporting operator's facility on the OCS must comply with this subpart. Compliance must extend from the point where hydrocarbons are first produced, through and including the last valve and associated safety equipment (e.g., pressure safety sensors) on the last production facility on the OCS.
(7)
Any producer operating a pipeline that connects facilities on the OCS must comply with this subpart.
(8)
Any operator of a pipeline that has a valve on the OCS downstream (landward) of the last production facility may ask in writing that the BSEE Regional Supervisor recognize that valve as the last point BSEE will exercise its regulatory authority.
(9)
A pipeline segment is not subject to BSEE regulations for design, construction, operation, and maintenance if:
(i)
It is downstream (generally shoreward) of the last valve and associated safety equipment on the last production facility on the OCS; and
(ii)
It is subject to regulation under 49 CFR parts 192 and 195.
(10)
DOT may inspect all upstream safety equipment (including valves, over-pressure protection devices, cathodic protection equipment, and pigging devices, etc.) that serve to protect the integrity of DOT-regulated pipeline segments.
(11)
OCS pipeline segments not subject to DOT regulation under 49 CFR parts 192 and 195 are subject to all BSEE regulations.
(12)
A producer may request that its pipeline operate under DOT regulations governing pipeline design, construction, operation, and maintenance.
(i)
The operator's request must be in the form of a written petition to the BSEE Regional Supervisor that states the justification for the pipeline to operate under DOT regulation.
(ii)
The Regional Supervisor will decide, on a case-by-case basis, whether to grant the operator's request. In considering each petition, the Regional Supervisor will consult with the appropriate DOT pipeline official.
(13)
A transporter who operates a pipeline regulated by DOT may request to operate under BSEE regulations governing pipeline operation and maintenance. Any subsequent repairs or modifications will also be subject to BSEE regulations governing design and construction.
(i)
The operator's request must be in the form of a written petition to the appropriate DOT pipeline official and the BSEE Regional Supervisor.
(ii)
The BSEE Regional Supervisor and the appropriate DOT pipeline official will decide how to act on this petition.
(d)
A pipeline which qualifies as a right-of-way pipeline (see § 250.1001, Definitions) shall not be installed until a right-of-way has been requested and granted in accordance with this subpart.
(e)
(1)
The Regional Supervisor may suspend any pipeline operation upon a determination by the Regional Supervisor that continued activity would threaten or result in serious, irreparable, or immediate harm or damage to life (including fish and other aquatic life), property, mineral deposits, or the marine, coastal, or human environment.
(2)
The Regional Supervisor may also suspend pipeline operations or a right-of-way grant if the Regional Supervisor determines that the lessee or right-of-way holder has failed to comply with a provision of the Act or any other applicable law, a provision of these or other applicable regulations, or a condition of a permit or right-of-way grant.
(3)
The Secretary of the Interior (Secretary) may cancel a pipeline permit or right-of-way grant in accordance with 43 U.S.C. 1334(a)(2). A right-of-way grant may be forfeited in accordance with 43 U.S.C. 1334(e).
Notes, amendments, and revision history

Amendments

[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36150, June 6, 2016]

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

[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36150, June 6, 2016]

§250.1001. Definitions.

30 C.F.R. § 250.1001

Terms used in this subpart shall have the meanings given below:

DOI pipelines include:

(1)
Producer-operated pipelines extending upstream (generally seaward) from each point on the OCS at which operating responsibility transfers from a producing operator to a transporting operator;
(2)
Producer-operated pipelines extending upstream (generally seaward) of the last valve (including associated safety equipment) on the last production facility on the OCS that do not connect to a transporter-operated pipeline on the OCS before crossing into State waters;
(3)
Producer-operated pipelines connecting production facilities on the OCS;
(4)
Transporter-operated pipelines that DOI and DOT have agreed are to be regulated as DOI pipelines; and
(5)
All OCS pipelines not subject to regulation under 49 CFR parts 192 and 195. DOT pipelines include:
(1)
Transporter-operated pipelines currently operated under DOT requirements governing design, construction, maintenance, and operation;
(2)
Producer-operated pipelines that DOI and DOT have agreed are to be regulated under DOT requirements governing design, construction, maintenance, and operation; and
(3)
Producer-operated pipelines downstream (generally shoreward) of the last valve (including associated safety equipment) on the last production facility on the OCS that do not connect to a transporter-operated pipeline on the OCS before crossing into State waters and that are regulated under 49 CFR parts 192 and 195.

Lease term pipelines are those pipelines owned and operated by a lessee or operator and are wholly contained within the boundaries of a single lease, unitized leases, or contiguous (not cornering) leases of that lessee or operator.

Out-of-service pipelines are those pipelines that have not been used to transport oil, natural gas, sulfur, or produced water for more than 30 consecutive days.

Pipelines are the piping, risers, and appurtenances installed for the purpose of transporting oil, gas, sulphur, and produced water. (Piping confined to a production platform or structure is covered in Subpart H, Production Safety Systems, and is excluded from this subpart.)

Production facilities means OCS facilities that receive hydrocarbon production either directly from wells or from other facilities that produce hydrocarbons from wells. They may include processing equipment for treating the production or separating it into its various liquid and gaseous components before transporting it to shore.

Right-of-way pipelines are those pipelines which—

(1)
Are contained within the boundaries of a single lease or group of unitized leases but are not owned and operated by the lessee or operator of that lease or unit,
(2)
Are contained within the boundaries of contiguous (not cornering) leases which do not have a common lessee or operator,
(3)
Are contained within the boundaries of contiguous (not cornering) leases which have a common lessee or operator but are not owned and operated by that common lessee or operator, or
(4)
Cross any portion of an unleased block(s).
Notes, amendments, and revision history

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.

§250.1002. Design requirements for DOI pipelines.

30 C.F.R. § 250.1002

(a)
The internal design pressure for steel pipe shall be determined in accordance with the following formula:

For limitations see section 841.121 of ANSI B31.8 (incorporated by reference, see § 250.198) where—

(b)
(1)
Pipeline valves shall meet the minimum design requirements of API Specification 6A, API Specification 6D (both incorporated by reference, see § 250.198), or the equivalent. A valve may not be used under operating conditions that exceed the applicable pressure-temperature ratings contained in those standards.
(2)
Pipeline flanges and flange accessories shall meet the minimum design requirements of ANSI/ASME B16.5-2003, API Specification 6A (incorporated by reference, see § 250.198), or the equivalent. Each flange assembly must be able to withstand the maximum pressure at which the pipeline is to be operated and to maintain its physical and chemical properties at any temperature to which it is anticipated that it might be subjected in service.
(3)
Pipeline fittings shall have pressure-temperature ratings based on stresses for pipe of the same or equivalent material. The actual bursting strength of the fitting shall at least be equal to the computed bursting strength of the pipe.
(4)
If you are installing pipelines constructed of unbonded flexible pipe, you must design them according to the standards and procedures of API Specification 17J (incorporated by reference, see § 250.198).
(5)
You must design pipeline risers for tension leg platforms and other floating platforms according to the design standards of API Recommended Practice 2RD (incorporated by reference, see § 250.198).
(c)
The maximum allowable operating pressure (MAOP) shall not exceed the least of the following:
(1)
Internal design pressure of the pipeline, valves, flanges, and fittings;
(2)
Eighty percent of the hydrostatic pressure test (HPT) pressure of the pipeline; or
(3)
If applicable, the MAOP of the receiving pipeline when the proposed pipeline and the receiving pipeline are connected at a subsea tie-in.
(d)
If the maximum source pressure (MSP) exceeds the pipeline's MAOP, you must install and maintain redundant safety devices meeting the requirements of section A9 of API Recommended Practice 14C (incorporated by reference, see § 250.198). Pressure safety valves (PSV) may be used only after a determination by the Regional Supervisor that the pressure will be relieved in a safe and pollution-free manner. The setting level at which the primary and redundant safety equipment actuates shall not exceed the pipeline's MAOP.
(e)
Pipelines shall be provided with an external protective coating capable of minimizing underfilm corrosion and a cathodic protection system designed to mitigate corrosion for at least 20 years.
(f)
Pipelines shall be designed and maintained to mitigate any reasonably anticipated detrimental effects of water currents, storm or ice scouring, soft bottoms, mud slides, earthquakes, subfreezing temperatures, and other environmental factors.
Notes, amendments, and revision history

Amendments

[76 FR 64462, Oct. 18, 2011, as amended at 83 FR 49263, Sept. 28, 2018; 91 FR 35359, June 10, 2026]

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

[76 FR 64462, Oct. 18, 2011, as amended at 83 FR 49263, Sept. 28, 2018; 91 FR 35359, June 10, 2026]

§250.1003. Installation, testing, and repair requirements for DOI pipelines.

30 C.F.R. § 250.1003

(a)
(1)
Pipelines greater than 8 5/8 inches in diameter and installed in water depths of less than 200 feet shall be buried to a depth of at least 3 feet unless they are located in pipeline congested areas or seismically active areas as determined by the Regional Supervisor. Nevertheless, the Regional Supervisor may require burial of any pipeline if the Regional Supervisor determines that such burial will reduce the likelihood of environmental degradation or that the pipeline may constitute a hazard to trawling operations or other uses. A trawl test or diver survey may be required to determine whether or not pipeline burial is necessary or to determine whether a pipeline has been properly buried.
(2)
Pipeline valves, taps, tie-ins, capped lines, and repaired sections that could be obstructive shall be provided with at least 3 feet of cover unless the Regional Supervisor determines that such items present no hazard to trawling or other operations. A protective device may be used to cover an obstruction in lieu of burial if it is approved by the Regional Supervisor prior to installation.
(3)
Pipelines shall be installed with a minimum separation of 18 inches at pipeline crossings and from obstructions.
(4)
Pipeline risers installed after April 1, 1988, shall be protected from physical damage that could result from contact with floating vessels. Riser protection on pipelines installed on or before April 1, 1988, may be required when the Regional Supervisor determines that significant damage potential exists.
(b)
(1)
Pipelines shall be pressure tested with water at a stabilized pressure of at least 1.25 times the MAOP for at least 8 hours when installed, relocated, uprated, or reactivated after being out-of-service for more than 1 year.
(2)
Prior to returning a pipeline to service after a repair, the pipeline shall be pressure tested with water or processed natural gas at a minimum stabilized pressure of at least 1.25 times the MAOP for at least 2 hours.
(3)
Pipelines shall not be pressure tested at a pressure which produces a stress in the pipeline in excess of 95 percent of the specified minimum-yield strength of the pipeline. A temperature recorder measuring test fluid temperature synchronized with a pressure recorder along with deadweight test readings shall be employed for all pressure testing. When a pipeline is pressure tested, no observable leakage shall be allowed. Pressure gauges and recorders shall be of sufficient accuracy to verify that leakage is not occurring.
(4)
The Regional Supervisor may require pressure testing of pipelines to verify the integrity of the system when the Regional Supervisor determines that there is a reasonable likelihood that the line has been damaged or weakened by external or internal conditions.
(c)
When a pipeline is repaired utilizing a clamp, the clamp shall be a full encirclement clamp able to withstand the anticipated pipeline pressure.
Notes, amendments, and revision history

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.

§250.1004. Safety equipment requirements for DOI pipelines.

30 C.F.R. § 250.1004

(a)
The lessee shall ensure the proper installation, operation, and maintenance of safety devices required by this section on all incoming, departing, and crossing pipelines on platforms.
(b)
(1)
(i)
Incoming pipelines to a platform shall be equipped with a flow safety valve (FSV).
(ii)
For sulphur operations, incoming pipelines delivering gas to the power plant platform may be equipped with high- and low-pressure sensors (PSHL), which activate audible and visual alarms in lieu of requirements in paragraph (b)(1)(i) of this section. The PSHL shall be set at 15 percent or 5 psi, whichever is greater, above and below the normal operating pressure range.
(2)
Incoming pipelines boarding a production platform shall be equipped with an automatic shutdown valve (SDV) immediately upon boarding the platform. The SDV shall be connected to the automatic- and remote-emergency shut-in systems.
(3)
Departing pipelines receiving production from production facilities shall be protected by high- and low-pressure sensors (PSHL) to directly or indirectly shut in all production facilities. The PSHL shall be set not to exceed 15 percent above and below the normal operating pressure range. However, high pilots shall not be set above the pipeline's MAOP.
(4)
Crossing pipelines on production or manned nonproduction platforms which do not receive production from the platform shall be equipped with an SDV immediately upon boarding the platform. The SDV shall be operated by a PSHL on the departing pipelines and connected to the platform automatic- and remote-emergency shut-in systems.
(5)
The Regional Supervisor may require that oil pipelines be equipped with a metering system to provide a continuous volumetric comparison between the input to the line at the structure(s) and the deliveries onshore. The system shall include an alarm system and shall be of adequate sensitivity to detect variations between input and discharge volumes. In lieu of the foregoing, a system capable of detecting leaks in the pipeline may be substituted with the approval of the Regional Supervisor.
(6)
Pipelines incoming to a subsea tie-in shall be equipped with a block valve and an FSV. Bidirectional pipelines connected to a subsea tie-in shall be equipped with only a block valve.
(7)
Gas-lift or water-injection pipelines on unmanned platforms need only be equipped with an FSV installed immediately upstream of each casing annulus or the first inlet valve on the christmas tree.
(8)
Bidirectional pipelines shall be equipped with a PSHL and an SDV immediately upon boarding each platform.
(9)
Pipeline pumps must comply with section A7 of API Recommended Practice 14C (incorporated by reference, see § 250.198). The setting levels for the PSHL devices are specified in paragraph (b)(3) of this section.
(c)
If the required safety equipment is rendered ineffective or removed from service on pipelines which are continued in operation, an equivalent degree of safety shall be provided. The safety equipment shall be identified by the placement of a sign on the equipment stating that the equipment is rendered ineffective or removed from service.
Notes, amendments, and revision history

Amendments

[76 FR 64462, Oct. 18, 2011, as amended at 91 FR 35360, June 10, 2026]

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

[76 FR 64462, Oct. 18, 2011, as amended at 91 FR 35360, June 10, 2026]

§250.1005. Inspection requirements for DOI pipelines.

30 C.F.R. § 250.1005

(a)
Pipeline routes shall be inspected at time intervals and methods prescribed by the Regional Supervisor for indication of pipeline leakage. The results of these inspections shall be retained for at least 2 years and be made available to the Regional Supervisor upon request.
(b)
When pipelines are protected by rectifiers or anodes for which the initial life expectancy of the cathodic protection system either cannot be calculated or calculations indicate a life expectancy of less than 20 years, such pipelines shall be inspected annually by taking measurements of pipe-to-electrolyte potential.
Notes, amendments, and revision history

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.

§250.1006. How must I decommission and take out of service a DOI pipeline?

30 C.F.R. § 250.1006

(a)
The requirements for decommissioning pipelines are listed in § 250.1750 through § 250.1754.
(b)
The table in this section lists the requirements if you take a DOI pipeline out of service—
Notes, amendments, and revision history

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.

§250.1007. What to include in applications.

30 C.F.R. § 250.1007

(a)
Applications to install a lease term pipeline or for a pipeline right-of-way grant must be submitted in quadruplicate to the Regional Supervisor. Right-of-way grant applications must include an identification of the operator of the pipeline. Each application must include the following:
(1)
Plat(s) drawn to a scale specified by the Regional Supervisor showing major features and other pertinent data including area, lease, and block designations; water depths; route; length in Federal waters; width of right-of-way, if applicable; connecting facilities; size; product(s) to be transported with anticipated gravity or density; burial depth; direction of flow; X-Y coordinates of key points; and the location of other pipelines that will be connected to or crossed by the proposed pipeline(s). The initial and terminal points of the pipeline and any continuation into State jurisdiction shall be accurately located even if the pipeline is to have an onshore terminal point. A plat(s) submitted for a pipeline right-of-way shall bear a signed certificate upon its face by the engineer who made the map that certifies that the right-of-way is accurately represented upon the map and that the design characteristics of the associated pipeline are in accordance with applicable regulations.
(2)
A schematic drawing showing the size, weight, grade, wall thickness, and type of line pipe and risers; pressure-regulating devices (including back-pressure regulators); sensing devices with associated pressure-control lines; PSV's and settings; SDV's, FSV's, and block valves; and manifolds. This schematic drawing shall also show input source(s), e.g., wells, pumps, compressors, and vessels; maximum input pressure(s); the rated working pressure, as specified by ANSI or API, of all valves, flanges, and fittings; the initial receiving equipment and its rated working pressure; and associated safety equipment and pig launchers and receivers. The schematic must indicate the point on the OCS at which operating responsibility transfers between a producing operator and a transporting operator.
(3)
General information as follows—
(i)
Description of cathodic protection system. If pipeline anodes are to be used, specify the type, size, weight, number, spacing, and anticipated life;
(ii)
Description of external pipeline coating system;
(iii)
Description of internal protective measures;
(iv)
Specific gravity of the empty pipe;
(v)
MSP;
(vi)
MAOP and calculations used in its determination;
(vii)
Hydrostatic test pressure, medium, and period of time that the line will be tested;
(viii)
MAOP of the receiving pipeline or facility,
(ix)
Proposed date for commencing installation and estimated time for construction; and
(x)
Type of protection to be afforded crossing pipelines, subsea valves, taps, and manifold assemblies, if applicable.
(4)
A description of any additional design precautions you took to enable the pipeline to withstand the effects of water currents, storm or ice scouring, soft bottoms, mudslides, earthquakes, permafrost, and other environmental factors.
(i)
If you propose to use unbonded flexible pipe, your application must include:
(A)
The manufacturer's design specification sheet;
(B)
The design pressure (psi);
(C)
An identification of the design standards you used; and
(D)
A review by a third-party independent verification agent (IVA) according to API Specification 17J (incorporated by reference, see § 250.198), if applicable.
(ii)
If you propose to use one or more pipeline risers for a tension leg platform or other floating platform, your application must include:
(A)
The design fatigue life of the riser, with calculations, and the fatigue point at which you would replace the riser;
(B)
The results of your vortex-induced vibration (VIV) analysis;
(C)
An identification of the design standards you used; and
(D)
A description of any necessary mitigation measures such as the use of helical strakes or anchoring devices.
(5)
The application shall include a shallow hazards survey report and, if required by the Regional Director, an archaeological resource report that covers the entire length of the pipeline. A shallow hazards analysis may be included in a lease term pipeline application in lieu of the shallow hazards survey report with the approval of the Regional Director. The Regional Director may require the submission of the data upon which the report or analysis is based.
(b)
Applications to modify an approved lease term pipeline or right-of-way grant shall be submitted in quadruplicate to the Regional Supervisor. These applications need only address those items in the original application affected by the proposed modification.
Notes, amendments, and revision history

Amendments

[76 FR 64462, Oct. 18, 2011, as amended at 83 FR 49263, Sept. 28, 2018; 91 FR 35360, June 10, 2026]

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

[76 FR 64462, Oct. 18, 2011, as amended at 83 FR 49263, Sept. 28, 2018; 91 FR 35360, June 10, 2026]

§250.1008. Reports.

30 C.F.R. § 250.1008

(a)
The lessee, or right-of-way holder, shall notify the Regional Supervisor at least 48 hours prior to commencing the installation or relocation of a pipeline or conducting a pressure test on a pipeline.
(b)
The lessee or right-of-way holder shall submit a report to the Regional Supervisor within 90 days after completion of any pipeline construction. The report, submitted in triplicate, shall include an “as-built” location plat drawn to a scale specified by the Regional Supervisor showing the location, length in Federal waters, and X-Y coordinates of key points; the completion date; the proposed date of first operation; and the HPT data. Pipeline right-of-way “as-built” location plats shall be certified by a registered engineer or land surveyor and show the boundaries of the right-of-way as granted. If there is a substantial deviation of the pipeline route as granted in the right-of-way, the report shall include a discussion of the reasons for such deviation.
(c)
The lessee or right-of-way holder shall report to the Regional Supervisor any pipeline taken out of service. If the period of time in which the pipeline is out of service is greater than 60 days, written confirmation is also required.
(d)
The lessee or right-of-way holder shall report to the Regional Supervisor when any required pipeline safety equipment is taken out of service for more than 12 hours. The Regional Supervisor shall be notified when the equipment is returned to service.
(e)
The lessee or right-of-way holder must notify the Regional Supervisor before the repair of any pipeline or as soon as practicable. Your notification must be accompanied by payment of the service fee listed in § 250.125. You must submit a detailed report of the repair of a pipeline or pipeline component to the Regional Supervisor within 30 days after the completion of the repairs. In the report you must include the following:
(1)
Description of repairs;
(2)
Results of pressure test; and
(3)
Date returned to service.
(f)
The Regional Supervisor may require that DOI pipeline failures be analyzed and that samples of a failed section be examined in a laboratory to assist in determining the cause of the failure. A comprehensive written report of the information obtained shall be submitted by the lessee to the Regional Supervisor as soon as available.
(g)
If the effects of scouring, soft bottoms, or other environmental factors are observed to be detrimentally affecting a pipeline, a plan of corrective action shall be submitted to the Regional Supervisor for approval within 30 days of the observation. A report of the remedial action taken shall be submitted to the Regional Supervisor by the lessee or right-of-way holder within 30 days after completion.
(h)
The results and conclusions of measurements of pipe-to-electrolyte potential measurements taken annually on DOI pipelines in accordance with § 250.1005(b) of this part shall be submitted to the Regional Supervisor by the lessee before March of each year.
Notes, amendments, and revision history

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.