eCFR for 1014-0007, 30 CFR Part 254

Title 30: Mineral Resources

PART 254—OIL-SPILL RESPONSE REQUIREMENTS FOR FACILITIES LOCATED SEAWARD
OF THE COAST LINE
Contents
Subpart A—General
§254.1
§254.2
§254.3
§254.4
§254.5
§254.6
§254.7
§254.8
§254.9

Who must submit an oil spill response plan (OSRP)?
When must I submit an OSRP?
May I cover more than one facility in my OSRP?
May I reference other documents in my OSRP?
General response plan requirements.
Definitions.
How do I submit my OSRP to the BSEE?
May I appeal decisions under this part?
Authority for information collection.

Subpart B—Oil-Spill Response Plans for Outer Continental Shelf Facilities
§254.20
§254.21
§254.22
§254.23
§254.24
§254.25
§254.26
§254.27
§254.28
§254.29
§254.30

Purpose.
How must I format my OSRP?
What information must I include in the “Introduction and OSRP contents” section?
What information must I include in the “Emergency response action plan” section?
What information must I include in the “Equipment inventory” appendix?
What information must I include in the “Contractual agreements” appendix?
What information must I include in the “Worst case discharge scenario” appendix?
What information must I include in the “Dispersant use plan” appendix?
What information must I include in the “In situ burning plan” appendix?
What information must I include in the “Training and drills” appendix?
When must I revise my OSRP?

Subpart C—Related Requirements for Outer Continental Shelf Facilities
§254.40
§254.41
§254.42
§254.43
§254.44
§254.45
§254.46
§254.47

Records.
Training your response personnel.
Exercises for your response personnel and equipment.
Maintenance and periodic inspection of response equipment.
Calculating response equipment effective daily recovery capacities.
Verifying the capabilities of your response equipment.
Whom do I notify if an oil spill occurs?
Determining the volume of oil of your worst case discharge scenario.

Subpart D—Oil-Spill Response Requirements for Facilities Located in State Waters Seaward
of the Coast Line

§254.50 Spill response plans for facilities located in State waters seaward of the coast line.
§254.51 Modifying an existing OCS OSRP.
§254.52 Following the format for an OCS OSRP.
§254.53 Submitting an OSRP developed under State requirements.
§254.54 Spill prevention for facilities located in State waters seaward of the coast line.
§254.55 Spill response plans for facilities located in Alaska State waters seaward of the coast line
in the Chukchi and Beaufort Seas.
Subpart E—Oil-Spill Response Requirements for Facilities Located on the Arctic OCS
§254.65 Purpose.
§§254.66-254.69 [Reserved]
§254.70 What are the additional requirements for facilities conducting exploratory drilling from a
MODU on the Arctic OCS?
§§254.71-254.79 [Reserved]
§254.80 What additional information must I include in the “Emergency response action plan”
section for facilities conducting exploratory drilling from a MODU on the Arctic OCS?
§§254.81-254.89 [Reserved]
§254.90 What are the additional requirements for exercises of your response personnel and
equipment for facilities conducting exploratory drilling from a MODU on the Arctic OCS?
AUTHORITY: 33 U.S.C. 1321.
SOURCE: 76 FR 64462, Oct. 18, 2011, unless otherwise noted.

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Subpart A—General
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§254.1 Who must submit an oil spill response plan (OSRP)?
(a) If you are the owner or operator of an oil handling, storage, or transportation facility, and it is
located seaward of the coast line, you must submit an oil spill response plan (OSRP) to BSEE for
approval. Your OSRP must demonstrate that you can respond quickly and effectively whenever oil is
discharged from your facility. Refer to §254.6 for the definitions of oil, facility, and coast line if you
have any doubts about whether to submit a plan.
(b) You must maintain a current OSRP for an abandoned facility until you physically remove or
dismantle the facility or until the Chief, Oil Spill Preparedness Division (OSPD) notifies you in writing
that a plan is no longer required.
(c) Owners or operators of offshore pipelines carrying essentially dry gas do not need to submit
a plan. You must, however, submit a plan for a pipeline that carries:
(1) Oil;
(2) Condensate that has been injected into the pipeline; or

(3) Gas and naturally occurring condensate.
(d) If you are in doubt as to whether you must submit a plan for an offshore facility or pipeline,
you should check with the Chief, OSPD.
(e) If your facility is located landward of the coast line, but you believe your facility is sufficiently
similar to OCS facilities that it should be regulated by BSEE, you may contact the Chief, OSPD, offer
to accept BSEE jurisdiction over your facility, and request that BSEE seek from the agency with
jurisdiction over your facility a relinquishment of that jurisdiction.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36151, June 6, 2016]

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§254.2 When must I submit an OSRP?
(a) You must submit, and BSEE must approve, an OSRP that covers each facility located
seaward of the coast line before you may use that facility. To continue operations, you must operate
the facility in compliance with the OSRP.
(b) Despite the provisions of paragraph (a) of this section, you may operate your facility after
you submit your OSRP while BSEE reviews it for approval. To operate a facility without an approved
OSRP, you must certify in writing to the Chief, OSPD that you have the capability to respond, to the
maximum extent practicable, to a worst case discharge or a substantial threat of such a discharge.
The certification must show that you have ensured by contract, or other means approved by the
Chief, OSPD, the availability of private personnel and equipment necessary to respond to the
discharge. Verification from the organization(s) providing the personnel and equipment must
accompany the certification. BSEE will not allow you to operate a facility for more than 2 years
without an approved OSRP.
[81 FR 36151, June 6, 2016]

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§254.3 May I cover more than one facility in my OSRP?
(a) Your OSRP may be for a single lease or facility or a group of leases or facilities. All the
leases or facilities in your plan must have the same owner or operator (including affiliates) and must
be located in the same BSEE Region (see definition of Regional OSRP in §254.6).
(b) Regional OSRPs must address all the elements required for an OSRP in subpart B, or
subpart D of this part, as appropriate.
(c) When developing a Regional OSRP, you may group leases or facilities subject to the
approval of the Chief, OSPD, for the purposes of:
(1) Calculating response times;
(2) Determining quantities of response equipment;
(3) Conducting oil-spill trajectory analyses;

(4) Determining worst case discharge scenarios; and
(5) Identifying areas of special economic and environmental importance that may be impacted
and the strategies for their protection.
(d) The Chief, OSPD, may specify how to address the elements of a Regional OSRP. The
Chief, OSPD, also may require that Regional OSRPs contain additional information if necessary for
compliance with appropriate laws and regulations.
[81 FR 36151, June 6, 2016]

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§254.4 May I reference other documents in my OSRP?
You may reference information contained in other readily accessible documents in your OSRP.
Examples of documents that you may reference are the National Contingency Plan (NCP), Area
Contingency Plan (ACP), BSEE or BOEM environmental documents, and Oil Spill Removal
Organization (OSRO) documents that are readily accessible to the Chief, OSPD. You must ensure
that the Chief, OSPD, possesses or is provided with copies of all OSRO documents you reference.
You should contact the Chief, OSPD, if you want to know whether a reference is acceptable.
[81 FR 36152, June 6, 2016]

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§254.5 General response plan requirements.
(a) The OSRP must provide for response to an oil spill from the facility. You must immediately
carry out the provisions of the OSRP whenever there is a release of oil from the facility. You must
also carry out the training, equipment testing, and periodic drills described in the OSRP, and these
measures must be sufficient to ensure the safety of the facility and to mitigate or prevent a discharge
or a substantial threat of a discharge.
(b) The OSRP must be consistent with the National Contingency Plan and the appropriate Area
Contingency Plan(s).
(c) Nothing in this part relieves you from taking all appropriate actions necessary to immediately
abate the source of a spill and remove any spills of oil.
(d) In addition to the requirements listed in this part, you must provide any other information the
Chief, OSPD, requires for compliance with appropriate laws and regulations.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016]

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§254.6 Definitions.
For the purposes of this part:

Adverse weather conditions means, for the purposes of this part, weather conditions found in
the operating area that make it difficult for response equipment and personnel to clean up or remove
spilled oil or hazardous substances. These conditions include, but are not limited to: fog,
inhospitable water and air temperatures, wind, sea ice, extreme cold, freezing spray, snow, currents,
sea states, and extended periods of low light. Adverse weather conditions do not refer to conditions
under which it would be dangerous or impossible to respond to a spill, such as a hurricane.
Arctic OCS means the Beaufort Sea and Chukchi Sea Planning Areas (for more information on
these areas, see the Proposed Final OCS Oil and Gas Leasing Program for 2012-2017 (June 2012)
at http://www.boem.gov/ Oil-and-Gas-Energy-Program/ Leasing/ Five-Year-Program/ 20122017/ Program-Area-Maps/ index.aspx).
Area Contingency Plan means an Area Contingency Plan prepared and published under
section 311(j) of the Federal Water Pollution Control Act (FWPCA).
Chief, OSPD means the Chief, BSEE Oil Spill Preparedness Division or designee.
Coast line means the line of ordinary low water along that portion of the coast which is in direct
contact with the open sea and the line marking the seaward limit of inland waters.
Discharge means any emission (other than natural seepage), intentional or unintentional, and
includes, but is not limited to, spilling, leaking, pumping, pouring, emitting, emptying, or dumping.
District Manager means the BSEE officer with authority and responsibility for a district within a
BSEE Region.
Facility means any structure, group of structures, equipment, or device (other than a vessel)
which is used for one or more of the following purposes: Exploring for, drilling for, producing, storing,
handling, transferring, processing, or transporting oil. The term excludes deep-water ports and their
associated pipelines as defined by the Deepwater Port Act of 1974, but includes other pipelines
used for one or more of these purposes. A mobile offshore drilling unit is classified as a facility when
engaged in drilling or downhole operations.
Ice intervention practices mean the equipment, vessels, and procedures used to increase oil
encounter rates and the effectiveness of spill response techniques and equipment when sea ice is
present.
Maximum extent practicable means within the limitations of available technology, as well as the
physical limitations of personnel, when responding to a worst case discharge in adverse weather
conditions.
National Contingency Plan means the National Oil and Hazardous Substances Pollution
Contingency Plan prepared and published under section 311(d) of the FWPCA, (33 U.S.C. 1321(d))
or revised under section 105 of the Comprehensive Environmental Response Compensation and
Liability Act (42 U.S.C. 9605).
National Contingency Plan Product Schedule means a schedule of dispersants and other
chemical or biological products, maintained by the Environmental Protection Agency, that may be
authorized for use on oil discharges in accordance with the procedures found at 40 CFR 300.910.

Oil means oil of any kind or in any form, including but not limited to petroleum, fuel oil, sludge,
oil refuse, and oil mixed with wastes other than dredged spoil. This also includes hydrocarbons
produced at the wellhead in liquid form (includes distillates or condensate associated with produced
natural gas), and condensate that has been separated from a gas prior to injection into a pipeline. It
does not include petroleum, including crude oil or any fraction thereof, which is specifically listed or
designated as a hazardous substance under paragraphs (A) through (F) of section 101(14) of the
Comprehensive Environmental Response, Compensation, and Liability Act (42 U.S.C. 9601) and
which is subject to the provisions of that Act. It also does not include animal fats and oils and
greases and fish and marine mammal oils, within the meaning of paragraph (2) of section 61(a) of
title 13, United States Code, and oils of vegetable origin, including oils from the seeds, nuts, and
kernels referred to in paragraph (1)(A) of that section.
Oil spill removal organization (OSRO) means an entity contracted by an owner or operator to
provide spill-response equipment and/or manpower in the event of an oil or hazardous substance
spill.
OSRP means an Oil Spill Response Plan.
Outer Continental Shelf means all submerged lands lying seaward and outside of the area of
lands beneath navigable waters as defined in section 2 of the Submerged Lands Act (43 U.S.C.
1301) and of which the subsoil and seabed appertain to the United States and are subject to its
jurisdiction and control.
Owner or operator means, in the case of an offshore facility, any person owning or operating
such offshore facility. In the case of any abandoned offshore facility, it means the person who owned
such facility immediately prior to such abandonment.
Pipeline means pipe and any associated equipment, appurtenance, or building used or
intended for use in the transportation of oil located seaward of the coast line, except those used for
deep-water ports. Pipelines do not include vessels such as barges or shuttle tankers used to
transport oil from facilities located seaward of the coast line.
Qualified individual means an English-speaking representative of an owner or operator, located
in the United States, available on a 24-hour basis, with full authority to obligate funds, carry out
removal actions, and communicate with the appropriate Federal officials and the persons providing
personnel and equipment in removal operations.
Regional Response Plan means a spill-response plan required by this part which covers
multiple facilities or leases of an owner or operator, including affiliates, which are located in the same
BSEE Region.
Regional Supervisor means the BSEE official with responsibility and authority for operations or
other designated program functions within a BSEE Region.
Remove means containment and cleanup of oil from water and shorelines or the taking of other
actions as may be necessary to minimize or mitigate damage to the public health or welfare,
including, but not limited to, fish, shellfish, wildlife, public and private property, shorelines, and
beaches.
Spill is synonymous with “discharge” for the purposes of this part.

Spill management team means the trained persons identified in an OSRP who staff the
organizational structure to manage spill response.
Spill-response coordinator means a trained person charged with the responsibility and
designated the commensurate authority for directing and coordinating response operations.
Spill-response operating team means the trained persons who respond to spills through
deployment and operation of oil-spill response equipment.
State waters located seaward of the coast line means the belt of the seas measured from the
coast line and extending seaward a distance of 3 miles (except the coast of Texas and the Gulf
coast of Florida, where the State waters extend seaward a distance of 3 leagues).
You means the owner or the operator as defined in this section.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016; 81 FR 46563, July 15, 2016]

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§254.7 How do I submit my OSRP to the BSEE?
You must submit the number of copies of your OSRP that the appropriate BSEE regional office
requires. If you prefer to use improved information technology such as electronic filing to submit your
plan, ask the Chief, OSPD, for further guidance.
(a) Send OSRPs for facilities located seaward of the coast line of Alaska to: Bureau of Safety
and Environmental Enforcement, Oil Spill Preparedness Division, Attention: Senior Analyst, 3801
Centerpoint Drive, Suite #500, Anchorage, AK 99503-5823.
(b) Send OSRPs for facilities in the Gulf of Mexico or Atlantic Ocean to: Bureau of Safety and
Environmental Enforcement, Oil Spill Preparedness Division, Attention: GOM Section Supervisor,
1201 Elmwood Park Boulevard, New Orleans, LA 70123-2394.
(c) Send OSRPs for facilities in the Pacific Ocean (except seaward of the coast line of Alaska)
to: Bureau of Safety and Environmental Enforcement, Oil Spill Preparedness Division, Attention:
Senior Analyst, 760 Paseo Camarillo, Suite 201, Camarillo, CA 93010-6002.
[81 FR 36152, June 6, 2016]

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§254.8 May I appeal decisions under this part?
See 30 CFR part 290 for instructions on how to appeal any order or decision that we issue
under this part.
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§254.9 Authority for information collection.

(a) The Office of Management and Budget (OMB) has approved the information collection
requirements in this part under 44 U.S.C. 3501 et seq. OMB assigned the control number 10140007. The title of this information collection is “30 CFR part 254, Oil Spill Response Requirements
for Facilities Located Seaward of the Coast line.”
(b) BSEE collects this information to ensure that the owner or operator of an offshore facility is
prepared to respond to an oil spill. BSEE uses the information to verify compliance with the
mandates of the Oil Pollution Act of 1990 (OPA). The requirement to submit this information is
mandatory. No confidential or proprietary information is collected.
(c) An agency may not conduct or sponsor, and a person is not required to respond to, a
collection of information unless it displays a currently valid OMB control number.
(d) Send comments regarding any aspect of the collection of information under this part,
including suggestions for reducing the burden, to the Information Collection Clearance Officer,
Bureau of Safety and Environmental Enforcement, 45600 Woodland Road, Sterling, VA 20166.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016]

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Subpart B—Oil-Spill Response Plans for Outer Continental Shelf
Facilities
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§254.20 Purpose.
This subpart describes the requirements for preparing OSRPs for facilities located on the OCS.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016]

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§254.21 How must I format my OSRP?
(a) You must divide your OSRP for OCS facilities into the sections specified in paragraph (b) of
this section and explained in the other sections of this subpart. The OSRP must have an easily
found marker identifying each section. You may use an alternate format if you include a cross
reference table to identify the location of required sections. You may use alternate contents if you
can demonstrate to the Chief, OSPD that they provide for equal or greater levels of preparedness.
(b) Your OSRP must include:
(1) Introduction and OSRP contents.
(2) Emergency response action plan.
(3) Appendices:

(i) Equipment inventory.
(ii) Contractual agreements.
(iii) Worst case discharge scenario.
(iv) Dispersant use plan.
(v) In situ burning plan.
(vi) Training and drills.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016]

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§254.22 What information must I include in the “Introduction and OSRP contents” section?
The “Introduction and OSRP contents” section must provide:
(a) Identification of the facility the OSRP covers, including its location and type;
(b) A table of contents;
(c) A record of changes made to the OSRP; and
(d) A cross-reference table, if needed, because you are using an alternate format for your
OSRP.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016]

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§254.23 What information must I include in the “Emergency response action plan” section?
The “Emergency response action plan” section is the core of the OSRP. Put information in
easy-to-use formats such as flow charts or tables where appropriate. This section must include:
(a) Designation, by name or position, of a trained qualified individual (QI) who has full authority
to implement removal actions and ensure immediate notification of appropriate Federal officials and
response personnel.
(b) Designation, by name or position, of a trained spill management team available on a 24hour basis. The team must include a trained spill-response coordinator and alternate(s) who have
the responsibility and authority to direct and coordinate response operations on your behalf. You
must describe the team's organizational structure as well as the responsibilities and authorities of
each position on the spill management team.
(c) Description of a spill-response operating team. Team members must be trained and
available on a 24-hour basis to deploy and operate spill-response equipment. They must be able to

respond within a reasonable minimum specified time. You must include the number and types of
personnel available from each identified labor source.
(d) A planned location for a spill-response operations center and provisions for primary and
alternate communications systems available for use in coordinating and directing spill-response
operations. You must provide telephone numbers for the response operations center. You also must
provide any facsimile numbers and primary and secondary radio frequencies that will be used.
(e) A listing of the types and characteristics of the oil handled, stored, or transported at the
facility.
(f) Procedures for the early detection of a spill.
(g) Identification of procedures you will follow in the event of a spill or a substantial threat of a
spill. The procedures should show appropriate response levels for differing spill sizes including those
resulting from a fire or explosion. These will include, as appropriate:
(1) Your procedures for spill notification. The plan must provide for the use of the oil spill
reporting forms included in the Area Contingency Plan or an equivalent reporting form.
(i) Your procedures must include a current list which identifies the following by name or
position, corporate address, and telephone number (including facsimile number if applicable):
(A) The qualified individual;
(B) The spill-response coordinator and alternate(s); and
(C) Other spill-response management team members.
(ii) You must also provide names, telephone numbers, and addresses for the following:
(A) OSRO's that the plan cites;
(B) Federal, State, and local regulatory agencies that you must consult to obtain site specific
environmental information; and
(C) Federal, State, and local regulatory agencies that you must notify when an oil spill occurs.
(2) Your methods to monitor and predict spill movement;
(3) Your methods to identify and prioritize the beaches, waterfowl, other marine and shoreline
resources, and areas of special economic and environmental importance;
(4) Your methods to protect beaches, waterfowl, other marine and shoreline resources, and
areas of special economic or environmental importance;
(5) Your methods to ensure that containment and recovery equipment as well as the response
personnel are mobilized and deployed at the spill site;

(6) Your methods to ensure that devices for the storage of recovered oil are sufficient to allow
containment and recovery operations to continue without interruption;
(7) Your procedures to remove oil and oiled debris from shallow waters and along shorelines
and rehabilitating waterfowl which become oiled;
(8) Your procedures to store, transfer, and dispose of recovered oil and oil-contaminated
materials and to ensure that all disposal is in accordance with Federal, State, and local
requirements; and
(9) Your methods to implement your dispersant use plan and your in situ burning plan.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016]

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§254.24 What information must I include in the “Equipment inventory” appendix?
Your “Equipment inventory appendix” must include:
(a) An inventory of spill-response materials and supplies, services, equipment, and response
vessels available locally and regionally. You must identify each supplier and provide their locations
and telephone numbers.
(b) A description of the procedures for inspecting and maintaining spill-response equipment in
accordance with §254.43.
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§254.25 What information must I include in the “Contractual agreements” appendix?
Your “Contractual agreements” appendix must furnish proof of any contracts or membership
agreements with OSRO's, cooperatives, spill-response service providers, or spill management team
members who are not your employees that you cite in the OSRP. To provide this proof, submit
copies of the contracts or membership agreements or certify that contracts or membership
agreements are in effect. The contract or membership agreement must include provisions for
ensuring the availability of the personnel and/or equipment on a 24-hour-per-day basis.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36152, June 6, 2016]

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§254.26 What information must I include in the “Worst case discharge scenario” appendix?
The discussion of your worst case discharge scenario must include all of the following
elements:
(a) The volume of your worst case discharge scenario determined using the criteria in §254.47.
Provide any assumptions made and the supporting calculations used to determine this volume.

(b) An appropriate trajectory analysis specific to the area in which the facility is located. The
analysis must identify onshore and offshore areas that a discharge potentially could affect. The
trajectory analysis chosen must reflect the maximum distance from the facility that oil could move in
a time period that it reasonably could be expected to persist in the environment.
(c) A list of the resources of special economic or environmental importance that potentially
could be impacted in the areas identified by your trajectory analysis. You also must state the
strategies that you will use for their protection. At a minimum, this list must include those resources
of special economic and environmental importance, if any, specified in the appropriate Area
Contingency Plan(s).
(d) A discussion of your response to your worst case discharge scenario in adverse weather
conditions. This discussion must include:
(1) A description of the response equipment that you will use to contain and recover the
discharge to the maximum extent practicable. This description must include the types, location(s)
and owner, quantity, and capabilities of the equipment. You also must include the effective daily
recovery capacities, where applicable. You must calculate the effective daily recovery capacities
using the methods described in §254.44. For operations at a drilling or production facility, your
scenario must show how you will cope with the initial spill volume upon arrival at the scene and then
support operations for a blowout lasting 30 days.
(2) A description of the personnel, materials, and support vessels that would be necessary to
ensure that the identified response equipment is deployed and operated promptly and effectively.
Your description must include the location and owner of these resources as well as the quantities
and types (if applicable);
(3) A description of your oil storage, transfer, and disposal equipment. Your description must
include the types, location and owner, quantity, and capacities of the equipment; and
(4) An estimation of the individual times needed for:
(i) Procurement of the identified containment, recovery, and storage equipment;
(ii) Procurement of equipment transportation vessel(s);
(iii) Procurement of personnel to load and operate the equipment;
(iv) Equipment loadout (transfer of equipment to transportation vessel(s));
(v) Travel to the deployment site (including any time required for travel from an equipment
storage area); and
(vi) Equipment deployment.
(e) In preparing the discussion required by paragraph (d) of this section, you must:
(1) Ensure that the response equipment, materials, support vessels, and strategies listed are
suitable, within the limits of current technology, for the range of environmental conditions anticipated
at your facility; and

(2) Use standardized, defined terms to describe the range of environmental conditions
anticipated and the capabilities of response equipment. Examples of acceptable terms include those
defined in American Society for Testing of Materials (ASTM) publication F625-94, Standard Practice
for Describing Environmental Conditions Relevant to Spill Control Systems for Use on Water, and
ASTM F818-93, Standard Definitions Relating to Spill Response Barriers.
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§254.27 What information must I include in the “Dispersant use plan” appendix?
Your dispersant use plan must be consistent with the National Contingency Plan Product
Schedule and other provisions of the National Contingency Plan and the appropriate Area
Contingency Plan(s). The plan must include:
(a) An inventory and a location of the dispersants and other chemical or biological products
which you might use on the oils handled, stored, or transported at the facility;
(b) A summary of toxicity data for these products;
(c) A description and a location of any application equipment required as well as an estimate of
the time to commence application after approval is obtained;
(d) A discussion of the application procedures;
(e) A discussion of the conditions under which product use may be requested; and
(f) An outline of the procedures you must follow in obtaining approval for product use.
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§254.28 What information must I include in the “In situ burning plan” appendix?
Your in situ burning plan must be consistent with any guidelines authorized by the National
Contingency Plan and the appropriate Area Contingency Plan(s). Your in situ burning plan must
include:
(a) A description of the in situ burn equipment including its availability, location, and owner;
spill;

(b) A discussion of your in situ burning procedures, including provisions for ignition of an oil
(c) A discussion of environmental effects of an in situ burn;
(d) Your guidelines for well control and safety of personnel and property;
(e) A discussion of the circumstances in which in situ burning may be appropriate;
(f) Your guidelines for making the decision to ignite; and
(g) An outline of the procedures you must follow to obtain approval for an in situ burn.

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§254.29 What information must I include in the “Training and drills” appendix?
Your “Training and drills” appendix must:
(a) Identify and include the dates of the training provided to members of the spill-response
management team and the qualified individual. The types of training given to the members of the
spill-response operating team also must be described. The training requirements for your spill
management team and your spill-response operating team are specified in §254.41. You must
designate a location where you keep course completion certificates or attendance records for this
training.
(b) Describe in detail your plans for satisfying the exercise requirements of §254.42. You must
designate a location where you keep the records of these exercises.
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§254.30 When must I revise my OSRP?
(a) You must review your OSRP at least every 2 years and submit all resulting modifications to
the Chief, OSPD. If this review does not result in modifications, you must inform the Chief, OSPD, in
writing that there are no changes.
(b) You must submit revisions to your OSRP for approval within 15 days whenever:
(1) A change occurs which significantly reduces your response capabilities;
(2) A significant change occurs in the worst case discharge scenario or in the type of oil being
handled, stored, or transported at the facility;
(3) There is a change in the name(s) or capabilities of the oil spill removal organizations cited in
the OSRP; or
(4) There is a significant change to the Area Contingency Plan(s).
(c) The Chief, OSPD, may require that you resubmit your OSRP if the OSRP has become
outdated or if numerous revisions have made its use difficult.
(d) The Chief, OSPD, will periodically review the equipment inventories of OSRO's to ensure
that sufficient spill removal equipment is available to meet the cumulative needs of the owners and
operators who cite these organizations in their OSRPs.
(e) The Chief, OSPD, may require you to revise your OSRP if significant inadequacies are
indicated by:
(1) Periodic reviews (described in paragraph (d) of this section);
(2) Information obtained during drills or actual spill responses; or

(3) Other relevant information the Chief, OSPD, obtained.
[81 FR 36152, June 6, 2016]

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Subpart C—Related Requirements for Outer Continental Shelf Facilities
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§254.40 Records.
You must make all records of services, personnel, and equipment provided by OSRO's or
cooperatives available to any authorized BSEE representative upon request.
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§254.41 Training your response personnel.
(a) You must ensure that the members of your spill-response operating team who are
responsible for operating response equipment attend hands-on training classes at least annually.
This training must include the deployment and operation of the response equipment they will use.
Those responsible for supervising the team must be trained annually in directing the deployment and
use of the response equipment.
(b) You must ensure that the spill-response management team, including the spill-response
coordinator and alternates, receives annual training. This training must include instruction on:
(1) Locations, intended use, deployment strategies, and the operational and logistical
requirements of response equipment;
(2) Spill reporting procedures;
(3) Oil-spill trajectory analysis and predicting spill movement; and
(4) Any other responsibilities the spill management team may have.
(c) You must ensure that the qualified individual is sufficiently trained to perform his or her
duties.
(d) You must keep all training certificates and training attendance records at the location
designated in your OSRP for at least 2 years. They must be made available to any authorized BSEE
representative upon request.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.42 Exercises for your response personnel and equipment.

(a) You must exercise your entire OSRP at least once every 3 years (triennial exercise). You
may satisfy this requirement by conducting separate exercises for individual parts of the OSRP over
the 3-year period; you do not have to exercise your entire OSRP at one time.
(b) In satisfying the triennial exercise requirement, you must, at a minimum, conduct:
(1) An annual spill management team tabletop exercise. The exercise must test the spill
management team's organization, communication, and decision making in managing a response.
You must not reveal the spill scenario to team members before the exercise starts.
(2) An annual deployment exercise of response equipment identified in your OSRP that is
staged at onshore locations. You must deploy and operate each type of equipment in each triennial
period. However, it is not necessary to deploy and operate each individual piece of equipment.
(3) An annual notification exercise for each facility that is manned on a 24- hour basis. The
exercise must test the ability of facility personnel to communicate pertinent information in a timely
manner to the qualified individual.
(4) A semiannual deployment exercise of any response equipment which the BSEE Regional
Supervisor requires an owner or operator to maintain at the facility or on dedicated vessels. You
must deploy and operate each type of this equipment at least once each year. Each type need not
be deployed and operated at each exercise.
(c) During your exercises, you must simulate conditions in the area of operations, including
seasonal weather variations, to the extent practicable. The exercises must cover a range of
scenarios over the 3-year exercise period, simulating responses to large continuous spills, spills of
short duration and limited volume, and your worst case discharge scenario.
(d) BSEE will recognize and give credit for any documented exercise conducted that satisfies
some part of the required triennial exercise. You will receive this credit whether the owner or
operator, an OSRO, or a Government regulatory agency initiates the exercise. BSEE will give you
credit for an actual spill response if you evaluate the response and generate a proper record.
Exercise documentation should include the following information:
(1) Type of exercise;
(2) Date and time of the exercise;
(3) Description of the exercise;
(4) Objectives met; and
(5) Lessons learned.
(e) All records of spill-response exercises must be maintained for the complete 3-year exercise
cycle. Records should be maintained at the facility or at a corporate location designated in the
OSRP. Records showing that OSROs and oil spill removal cooperatives have deployed each type of
equipment also must be maintained for the 3-year cycle.

(f) You must inform the Chief, OSPD of the date of any exercise required by paragraph (b)(1),
(2), or (4) of this section at least 30 days before the exercise. This will allow BSEE personnel the
opportunity to witness any exercises.
(g) The Regional Supervisor periodically will initiate unannounced drills to test the spill
response preparedness of owners and operators.
(h) The Chief, OSPD may require changes in the frequency or location of the required
exercises, equipment to be deployed and operated, or deployment procedures or strategies. The
Chief, OSPD may evaluate the results of the exercises and advise the owner or operator of any
needed changes in response equipment, procedures, or strategies.
(i) Compliance with the National Preparedness for Response Exercise Program (PREP)
Guidelines will satisfy the exercise requirements of this section. Copies of the PREP document may
be obtained from the Chief, OSPD.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.43 Maintenance and periodic inspection of response equipment.
(a) You must ensure that the response equipment listed in your OSRP is inspected at least
monthly and is maintained, as necessary, to ensure optimal performance.
(b) You must ensure that records of the inspections and the maintenance activities are kept for
at least 2 years and are made available to any authorized BSEE representative upon request.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.44 Calculating response equipment effective daily recovery capacities.
(a) You are required by §254.26(d)(1) to calculate the effective daily recovery capacity of the
response equipment identified in your OSRP that you would use to contain and recover your worst
case discharge. You must calculate the effective daily recovery capacity of the equipment by
multiplying the manufacturer's rated throughput capacity over a 24-hour period by 20 percent. This
20 percent efficiency factor takes into account the limitations of the recovery operations due to
available daylight, sea state, temperature, viscosity, and emulsification of the oil being recovered.
You must use this calculated rate to determine if you have sufficient recovery capacity to respond to
your worst case discharge scenario.
(b) If you want to use a different efficiency factor for specific oil recovery devices, you must
submit evidence to substantiate that efficiency factor. Adequate evidence includes verified
performance data measured during actual spills or test data gathered according to the provisions of
§254.45(b) and (c).
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.45 Verifying the capabilities of your response equipment.
(a) The Regional Supervisor may require performance testing of any spill-response equipment
listed in your OSRP to verify its capabilities if the equipment:
(1) Has been modified;
(2) Has been damaged and repaired; or
(3) Has a claimed effective daily recovery capacity that is inconsistent with data otherwise
available to BSEE.
(b) You must conduct any required performance testing of booms in accordance with BSEEapproved test criteria. You may use the document “Test Protocol for the Evaluation of Oil-Spill
Containment Booms,” available from BSEE, for guidance. Performance testing of skimmers also
must be conducted in accordance with BSEE approved test criteria. You may use the document
“Suggested Test Protocol for the Evaluation of Oil Spill Skimmers for the OCS,” available from
BSEE, for guidance.
(c) You are responsible for any required testing of equipment performance and for the accuracy
of the information submitted.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.46 Whom do I notify if an oil spill occurs?
(a) You must immediately notify the National Response Center (1-800-424-8802) if you
observe:
(1) An oil spill from your facility;
(2) An oil spill from another offshore facility; or
(3) An offshore spill of unknown origin.
(b) In the event of a spill of 1 barrel or more from your facility, you must orally notify the
Regional Supervisor without delay. You also must report spills from your facility of unknown size but
thought to be 1 barrel or more.
(1) If a spill from your facility not originally reported to the Regional Supervisor is subsequently
found to be 1 barrel or more, you must then report it without delay.
(2) You must file a written follow up report for any spill from your facility of 1 barrel or more. The
Chief, OSPD must receive this confirmation within 15 days after the spillage has been stopped. All
reports must include the cause, location, volume, and remedial action taken. Reports of spills of
more than 50 barrels must include information on the sea state, meteorological conditions, and the
size and appearance of the slick. The Regional Supervisor may require additional information if it is
determined that an analysis of the response is necessary.

(c) If you observe a spill resulting from operations at another offshore facility, you must
immediately notify the responsible party and the Regional Supervisor.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.47 Determining the volume of oil of your worst case discharge scenario.
You must calculate the volume of oil of your worst case discharge scenario as follows:
(a) For an oil production platform facility, the size of your worst case discharge scenario is the
sum of the following:
(1) The maximum capacity of all oil storage tanks and flow lines on the facility. Flow line volume
may be estimated; and
(2) The volume of oil calculated to leak from a break in any pipelines connected to the facility
considering shutdown time, the effect of hydrostatic pressure, gravity, frictional wall forces and other
factors; and
(3) The daily production volume from an uncontrolled blowout of the highest capacity well
associated with the facility. In determining the daily discharge rate, you must consider reservoir
characteristics, casing/production tubing sizes, and historical production and reservoir pressure data.
Your scenario must discuss how to respond to this well flowing for 30 days as required by
§254.26(d)(1).
(b) For exploratory or development drilling operations, the size of your worst case discharge
scenario is the daily volume possible from an uncontrolled blowout. In determining the daily
discharge rate, you must consider any known reservoir characteristics. If reservoir characteristics
are unknown, you must consider the characteristics of any analog reservoirs from the area and give
an explanation for the selection of the reservoir(s) used. Your scenario must discuss how to respond
to this well flowing for 30 days as required by §254.26(d)(1).
(c) For a pipeline facility, the size of your worst case discharge scenario is the volume possible
from a pipeline break. You must calculate this volume as follows:
(1) Add the pipeline system leak detection time to the shutdown response time.
(2) Multiply the time calculated in paragraph (c)(1) of this section by the highest measured oil
flow rate over the preceding 12-month period. For new pipelines, you should use the predicted oil
flow rate in the calculation.
(3) Add to the volume calculated in paragraph (c)(2) of this section the total volume of oil that
would leak from the pipeline after it is shut in. Calculate this volume by taking into account the
effects of hydrostatic pressure, gravity, frictional wall forces, length of pipeline segment, tie-ins with
other pipelines, and other factors.
(d) If your facility which stores, handles, transfers, processes, or transports oil does not fall into
the categories listed in paragraph (a), (b), or (c) of this section, contact the Chief, OSPD for
instructions on the calculation of the volume of your worst case discharge scenario.

[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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Subpart D—Oil-Spill Response Requirements for Facilities Located in
State Waters Seaward of the Coast Line
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§254.50 Spill response plans for facilities located in State waters seaward of the coast line.
Owners or operators of facilities located in State waters seaward of the coast line must submit
a spill-response plan to BSEE for approval. You may choose one of three methods to comply with
this requirement. The three methods are described in §§254.51, 254.52, and 254.53.
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§254.51 Modifying an existing OCS OSRP.
You may modify an existing response plan covering a lease or facility on the OCS to include a
lease or facility in State waters located seaward of the coast line. Since this OSRP would cover more
than one lease or facility, it would be considered a Regional Response Plan. You should refer to
§254.3 and contact the appropriate regional BSEE office if you have any questions on how to
prepare this Regional Response Plan.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.52 Following the format for an OCS OSRP.
You may develop a response OSRP following the requirements for plans for OCS facilities
found in subpart B of this part.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.53 Submitting an OSRP developed under State requirements.
(a) You may submit a response plan to BSEE for approval that you developed in accordance
with the laws or regulations of the appropriate State. The OSRP must contain all the elements the
State and OPA require and must:
(1) Be consistent with the requirements of the National Contingency Plan and appropriate Area
Contingency Plan(s).
(2) Identify a qualified individual and require immediate communication between that person
and appropriate Federal officials and response personnel if there is a spill.

(3) Identify any private personnel and equipment necessary to remove, to the maximum extent
practicable, a worst case discharge as defined in §254.47. The plan must provide proof of
contractual services or other evidence of a contractual agreement with any OSRO's or spill
management team members who are not employees of the owner or operator.
(4) Describe the training, equipment testing, periodic unannounced drills, and response actions
of personnel at the facility. These must ensure both the safety of the facility and the mitigation or
prevention of a discharge or the substantial threat of a discharge.
(5) Describe the procedures you will use to periodically update and resubmit the plan for
approval of each significant change.
(b) Your plan developed under State requirements also must include the following information:
(1) A list of the facilities and leases the plan covers and a map showing their location;
(2) A list of the types of oil handled, stored, or transported at the facility;
(3) Name and address of the State agency to whom the plan was submitted;
(4) Date you submitted the plan to the State;
(5) If the plan received formal approval, the name of the approving organization, the date of
approval, and a copy of the State agency's approval letter if one was issued; and
(6) Identification of any regulations or standards used in preparing the plan.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.54 Spill prevention for facilities located in State waters seaward of the coast line.
In addition to your OSRP, you must submit to the Regional Supervisor a description of the
steps you are taking to prevent spills of oil or mitigate a substantial threat of such a discharge. You
must identify all State or Federal safety or pollution prevention requirements that apply to the
prevention of oil spills from your facility, and demonstrate your compliance with these requirements.
You also should include a description of industry safety and pollution prevention standards your
facility meets. The Chief, OSPD may prescribe additional equipment or procedures for spill
prevention if it is determined that your efforts to prevent spills do not reflect good industry practices.
[76 FR 64462, Oct. 18, 2011, as amended at 81 FR 36153, June 6, 2016]

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§254.55 Spill response plans for facilities located in Alaska State waters seaward of the
coast line in the Chukchi and Beaufort Seas.
Response plans for facilities conducting exploratory drilling operations from a MODU seaward
of the coast line in Alaska State waters in the Chukchi and Beaufort Seas must follow the

requirements contained within subpart E of this part, in addition to the other requirements of this
subpart. Such response plans must address how the source control procedures selected to comply
with State law will be integrated into the planning, training, and exercise requirements of
§§254.70(a), 254.90(a), and 254.90(c), in the event that the proposed operations do not incorporate
the capping stack, cap and flow system, containment dome, and/or other similar subsea and surface
devices and equipment and vessels referenced in those sections.
[81 FR 46563, July 15, 2016]

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Subpart E—Oil-Spill Response Requirements for Facilities Located on
the Arctic OCS
SOURCE: 81 FR 46564, July 15, 2016, unless otherwise noted.

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§254.65 Purpose.
This subpart describes the additional requirements for preparing OSRPs and maintaining oil
spill preparedness for facilities conducting exploratory drilling operations from a mobile offshore
drilling unit (MODU) on the Arctic OCS.
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§§254.66-254.69 [Reserved]
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§254.70 What are the additional requirements for facilities conducting exploratory drilling
from a MODU on the Arctic OCS?
In addition to meeting the applicable requirements of this part, your OSRP must:
(a) Describe how the relevant personnel, equipment, materials, and support vessels associated
with the capping stack, cap and flow system, containment dome, and other similar subsea and
surface devices and equipment and vessels will be integrated into oil spill response incident action
planning;
(b) Describe how you will address human factors, such as cold stress and cold related
conditions, associated with oil spill response activities in adverse weather conditions and their
impacts on decision-making and health and safety; and
(c) Undergo plan-holder review prior to handling, storing, or transporting oil in connection with
seasonal exploratory drilling activities, and all resulting modifications must be submitted to the
Regional Supervisor. If this review does not result in modifications, you must inform the Regional
Supervisor in writing that there are no changes. The requirements of this paragraph (c) are in lieu of
the requirements in §254.30(a).

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§§254.71-254.79 [Reserved]
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§254.80 What additional information must I include in the “Emergency response action plan”
section for facilities conducting exploratory drilling from a MODU on the Arctic OCS?
In addition to the requirements in §254.23, you must include the following information in the
emergency response action plan section of your OSRP:
(a) A description of your ice intervention practices and how they will improve the effectiveness
of the oil spill response options and strategies that are listed in your OSRP in the presence of sea
ice. When developing the ice intervention practices for your OSRP, you must consider, at a
minimum, the use of specialized tactics, modified response equipment, ice management assist
vessels, and technologies for the identification, tracking, containment and removal of oil in ice.
(b) On areas of the Arctic OCS where a planned shore-based response would not satisfy
§254.1(a):
(1) A list of all resources required to ensure an effective offshore-based response capable of
operating in adverse weather conditions. This list must include a description of how you will ensure
the shortest possible transit times, including but not limited to establishing an offshore resource
management capability (e.g., sea-based staging, maintenance, and berthing logistics); and
(2) A list and description of logistics resupply chains, including waste management, that
effectively factor in the remote and limited infrastructure that exists in the Arctic and ensure you can
adequately sustain all oil spill response activities for the duration of the response. The components
of the logistics supply chain include, but are not limited to:
(i) Personnel and equipment transport services;
(ii) Airfields and types of aircraft that can be supported;
(iii) Capabilities to mobilize supplies (e.g., response equipment, fuel, food, fresh water) and
personnel to the response sites;
(iv) Onshore staging areas, storage areas that may be used en-route to staging areas, and
camp facilities to support response personnel conducting offshore, nearshore and shoreline
response; and
(v) Management of recovered fluid and contaminated debris and response materials (e.g., oiled
sorbents), as well as waste streams generated at offshore and on-shore support facilities (e.g.,
sewage, food, and medical).
(c) A description of the system you will use to maintain real-time location tracking for all
response resources while operating, transiting, or staging/maintaining such resources during a spill
response.
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§§254.81-254.89 [Reserved]
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§254.90 What are the additional requirements for exercises of your response personnel and
equipment for facilities conducting exploratory drilling from a MODU on the Arctic OCS?
In addition to the requirements in §254.42, the following requirements apply to exercises for
your response personnel and equipment for facilities conducting exploratory drilling from a MODU on
the Arctic OCS:
(a) You must incorporate the personnel, materials, and equipment identified in §254.70(a), the
safe working practices identified in §254.70(b), the ice intervention practices described in
§254.80(a), the offshore-based response requirements in §254.80(b), and the resource tracking
requirements in §254.80(c) into your spill-response training and exercise activities.
(b) For each season in which you plan to conduct exploratory drilling operations from a MODU
on the Arctic OCS, you must notify the Regional Supervisor 60 days prior to handling, storing, or
transporting oil.
(c) After the Regional Supervisor receives notice pursuant to §254.90(b), the Regional
Supervisor may direct you to deploy and operate your spill response equipment and/or your capping
stack, cap and flow system, and containment dome, and other similar subsea and surface devices
and equipment and vessels, as part of announced or unannounced exercises or compliance
inspections. For the purposes of this section, spill response equipment does not include the use of
blowout preventers, diverters, heavy weight mud to kill the well, relief wells, or other similar
conventional well control options.