If, during drilling, gas is lost as a result of loss of well control, the operator must notify the BLM within 24 hours of the start of the loss of the well control event and submit to the BLM a Sundry Notice within 15 days following the conclusion of the event describing the loss of well control. The BLM will determine whether the loss of well control was due to operator negligence. Oil or gas lost as a result of loss of well control is avoidably lost if the BLM determines that the loss of well control was due to operator negligence. The BLM will notify the operator in writing when it determines whether oil or gas was lost due to operator negligence, and whether such loss will qualify as an avoidable loss.

(a) Gas flared following well completion or recompletion is royalty-free under §§ 3179.41(b)(2) and 3179.42(b) until one of the following occurs:

(1) Thirty days have passed since the beginning of the flowback following completion or recompletion, except as provided in paragraphs (b) and (d) of this section;

(2) The operator has flared 20,000 Mcf of gas; or

(3) Flowback has been routed to the production separator.

(b) The BLM may extend the period specified in paragraph (a)(1) of this section, not to exceed an additional 60 days, based on flowback delays caused by well or equipment problems.

(c) The BLM may increase the limit specified in paragraph (a)(2) of this section by up to an additional 30,000 Mcf of gas for exploratory oil wells in remote locations where additional flaring may be needed in advance of construction of pipeline infrastructure.

(d) During the dewatering and initial evaluation of an exploratory coalbed methane well, the 30-day period specified in paragraph (a)(1) of this section is extended to 90 days. The BLM may approve up to two extensions of this evaluation period, not to exceed 90 days per each approval.

(e) The operator must submit its request for an extension under paragraphs (b), (c), or (d) of this section using a Sundry Notice.

During well tests subsequent to the initial completion or recompletion, the operator may flare gas royalty free under § 3179.41(b)(3) for no more than 24 hours, unless the BLM approves or requires a longer period. The operator must submit any such request using a Sundry Notice.

(a) An operator may flare or, if flaring is not feasible due to the emergency situation, vent gas royalty-free under § 3179.41(b)(5) for no longer than 48 hours during an emergency situation. For purposes of this subpart, an “emergency situation” is a temporary, infrequent, and unavoidable situation in which the loss of gas is necessary to avoid a danger to human health, safety, or the environment.

(b) The following examples do not constitute emergency situations for the purposes of royalty assessment:

(1) Recurring failures of a single piece of equipment;

(2) The operator's failure to install appropriate equipment of a sufficient capacity to accommodate the production conditions;

(3) Failure to limit production when the production rate exceeds the capacity of the related equipment, pipeline, or gas plant, or exceeds sales contract volumes of oil or gas;

(4) Scheduled maintenance; or

(5) A situation caused by operator negligence.

(c) Within 45 days of the start of the emergency, the operator must estimate and report to the AO by a Sundry Notice the volumes flared or vented beyond the timeframe specified in paragraph (a) of this section, and details describing the emergency event, measures taken to prevent the emergency event, and actions taken to control the emergency event so that the BLM is able to determine if the loss of oil or gas is an unavoidable loss pursuant to § 3179.41.

The purpose of this subpart is to implement and carry out the purposes of statutes relating to prevention of waste from Federal and Indian (other than The Osage Nation) oil and gas leases, protection of worker safety, conservation of surface resources, and management of the public lands for multiple use and sustained yield. This subpart supersedes those portions of Notice to Lessees and Operators of Onshore Federal and Indian Oil and Gas Leases, Royalty or Compensation for Oil and Gas Lost (NTL-4A) pertaining to, among other things, flaring and venting of produced gas, unavoidably and avoidably lost gas, and waste prevention.

(a) Except as provided in provided paragraph (b), this subpart applies to:

(1) All onshore Federal and Indian (other than The Osage Nation) oil and gas leases, units, and communitized areas;

(2) Indian Mineral Development Act (IMDA) agreements, unless specifically excluded in the agreement or unless the relevant provisions of this subpart are inconsistent with the agreement;

(3) Leases and other business agreements and contracts for the development of Tribal energy resources under a Tribal Energy Resource Agreement (TERA) entered into with the Secretary, unless specifically excluded in the lease, other business agreement, or TERA;

(4) Wells, equipment, and operations on State or private tracts that are committed to a federally approved unit or communitization agreement defined by or established under 43 CFR subpart 3105 or 43 CFR part 3180.

(b) Sections 3179.50, 3179.90, and 3179.100 through 3179.102 apply only to operations and production equipment located on a Federal or Indian surface estate. They do not apply to operations and production equipment on State or private tracts, even where those tracts are committed to a federally approved unit or communitization agreement.

(c) For purposes of this subpart, the term “lease” also includes IMDA agreements.

As used in this subpart, the term:

Automatic ignition system means an automatic ignitor and, where necessary to ensure continuous combustion, a continuous pilot flame.

Capture means the physical containment of natural gas for transportation to market or productive use of natural gas and includes reinjection and royalty-free on-site uses pursuant to subpart 3178.

Compressor station means any permanent combination of one or more compressors that move natural gas at increased pressure through gathering or transmission pipelines, or into or out of storage. This includes, but is not limited to, gathering and boosting stations and transmission compressor stations. The combination of one or more compressors located at a well site, or located at an onshore natural gas processing plant, is not a compressor station.

Gas-to-oil ratio (GOR) means the ratio of gas to oil in the production stream expressed in standard cubic feet of gas per barrel of oil at standard conditions.

Gas well means a well for which the energy equivalent of the gas produced, including its entrained liquefiable hydrocarbons, exceeds the energy equivalent of the oil produced. Unless more specific British thermal unit (Btu) values are available, a well with a gas-to-oil ratio greater than 6,000 standard cubic feet (scf) of gas per barrel of oil is a gas well.

High-pressure flare means an open-air flare stack or flare pit designed for the combustion of natural gas that would normally go to sales.

Leak means a release of natural gas from a component that is not associated with normal operation of the component, when such release is:

(1) A hydrocarbon emission detected by use of an optical-gas-imaging instrument;

(2) At least 500 ppm of hydrocarbon detected using a portable analyzer or other instrument that can measure the quantity of the release; or

(3) A hydrocarbon emission detected via audio, visual, and olfactory means or visible bubbles detected using soap solution. Releases due to normal operation of equipment intended to vent as part of normal operations, such as gas-driven pneumatic controllers and safety-release devices, are not leaks unless the releases exceed the quantities and frequencies expected during normal operations. Releases due to operator errors or equipment malfunctions or from control equipment at levels that exceed applicable regulatory requirements, such as releases from an oil storage tank hatch left open, or an improperly sized combustor, are leaks.

Liquids unloading means the removal of an accumulation of liquid hydrocarbons or water from the wellbore of a completed gas well.

Lost oil or lost gas means produced oil or gas that escapes containment, either intentionally or unintentionally, or is flared before being removed from the lease, unit, or communitized area, and cannot be recovered.

Low-pressure flare means any flare that does not meet the definition of high-pressure flare.

Pneumatic controller means an automated instrument used for maintaining a process condition, such as liquid level, pressure, delta-pressure, or temperature.

If a court holds any provisions of the regulations in this subpart or their applicability to any person or circumstances invalid, the remainder of this subpart and its applicability to other people or circumstances will not be affected.

Certain material is incorporated by reference into this subpart with the approval of the Director of the Federal Register under 5 U.S.C. 552(a) and 1 CFR part 51. To enforce any edition other than that specified in this section, the BLM must publish a rule in the Federal Register, and the material must be reasonably available to the public. All approved incorporation by reference (IBR) material is available for inspection at the Bureau of Land Management (BLM) and at the National Archives and Records Administration (NARA). Contact Yvette M. Fields with the BLM at: Division of Fluid Minerals, 1849 C Street NW, Washington, DC 20240, telephone 240-712-8358; email [email protected]; https://www.blm.gov/programs/energy-and-minerals/oil-and-gas. The approved material is also available for inspection at all BLM offices with jurisdiction over oil and gas activities. For information on inspecting this material at NARA, visit www.archives.gov/federal-register/cfr/ibr-locations.html or email [email protected]. The material may be obtained from the following source:

(a) American Petroleum Institute (API), 200 Massachusetts Ave. NW, Suite 1100, Washington, DC 20001; telephone 202-682-8000. API offers free, read-only access to some of the material at http://publications.api.org.

(1) API Manual of Petroleum Measurement Standards Chapter 22.3, Testing Protocol for Flare Gas Metering; First Edition, August 2015 (“API 22.3”), IBR approved for § 3179.71(c).

(2) [Reserved]

(b) [Reserved]

(a) Operators must use all reasonable precautions to prevent the waste of oil or gas developed from the lease.

(b) The Authorized Officer may specify reasonable measures to prevent waste as conditions of approval of an Application for Permit to Drill (APD).

(c) After an APD is approved, the Authorized Officer may order an operator to implement, within a reasonable time, additional reasonable measures to prevent waste at ongoing exploration and production operations.

(d) Reasonable measures to prevent waste may reflect factors including, but not limited to, relevant advances in technology and changes in industry practice.

For purposes of this subpart:

(a) Lost oil is “unavoidably lost” if the operator has taken reasonable steps to avoid waste, and the operator has complied fully with applicable laws, lease terms, regulations, provisions of a previously approved operating plan, and other written orders of the BLM.

(b) Lost gas is “unavoidably lost” if the operator has taken reasonable steps to avoid waste, the operator has complied fully with applicable laws, lease terms, regulations, provisions of a previously approved operating plan, and other written orders of the BLM; and the gas is lost from the following operations or sources:

(1) Well drilling, subject to the limitations in § 3179.80;

(2) Well completion and recompletion flaring allowances in § 3179.81;

(3) Subsequent well tests, subject to the limitations in § 3179.82;

(4) Exploratory coalbed methane well dewatering;

(5) Emergency situations, subject to the limitations in § 3179.83;

(6) Normal operating losses from a natural-gas-activated pneumatic controller or pump;

(7) Normal operating losses from an oil storage tank or other low-pressure production vessel that is in compliance with §§ 3179.90 and 3174.5(b);

(8) Well venting in the course of downhole well maintenance and/or liquids unloading performed in compliance with § 3179.91;

(9) Leaks, when the operator has complied with the LDAR requirements in §§ 3179.100 and 3179.101;

(10) Facility and pipeline maintenance, such as when an operator must blow-down and depressurize equipment to perform maintenance or repairs;

(11) Pipeline capacity constraints, midstream processing failures, or other similar events that prevent oil-well gas from being transported through the connected pipeline, subject to the limitations in the WMP or self-certification for Applications for Permit to Drill approved after June 10, 2024 or § 3179.70, as applicable;

(12) Flaring of gas from which at least 50 percent of natural gas liquids have been removed on-lease and captured for market, if the operator has notified the BLM through a Sundry Notices and Report on Wells, Form 3160-5 (Sundry Notice) that the operator is conducting such capture and the inlet of the equipment used to remove the natural gas liquids will be a Facility Measurement Point (FMP); or

(13) Flaring of gas from a well that is not connected to a gas pipeline, to the extent that such flaring was authorized by the BLM in the approval of the APD.

(c) Lost oil or gas that is not “unavoidably lost” as defined in paragraphs (a) and (b) of this section is “avoidably lost.”

(a) Royalty is due on all avoidably lost oil or gas.

(b) Royalty is not due on any unavoidably lost oil or gas.

(a) Table 1 is a summary of the Sundry Notice requirements in this subpart.

(b) Table 2 summarizes the locations in this subpart that require an operator to provide information to the authorized officer upon request.

(c) Table 3 summarizes the initial LDAR program submission and subsequent annual reporting.

(a) The operator must flare, rather than vent, any gas that is not captured, except when:

(1) Flaring the gas is technically infeasible, such as when volumes are too small to flare;

(2) Under emergency conditions, the loss of gas is uncontrollable, or venting is necessary for safety;

(3) The gas is vented through normal operation of a natural-gas-activated pneumatic controller or pump;

(4) The gas is vented from an oil storage tank;

(5) The gas is vented during downhole well maintenance or liquids unloading activities performed in compliance with § 3179.91;

(6) The gas is vented through a leak;

(7) Venting is necessary to allow non-routine facility and pipeline maintenance, such as when an operator must, upon occasion, blow-down and depressurize equipment to perform maintenance or repairs; or

(8) A release of gas is necessary and flaring is prohibited by Federal, State, local, or Tribal law or regulation, or enforceable permit term.

(b) All flares or combustion devices must be equipped with an automatic ignition system or an on-demand ignition system. Upon discovery of a flare that is venting instead of combusting gas, the BLM may subject the operator to an immediate assessment of $1,000 per violation.

(c) The flare must be placed a sufficient distance from the tanks' containment area and any other significant structures or objects so that the flare does not create a safety hazard. The prevailing wind direction must be taken into consideration when locating the flare.

Gas-well gas may not be flared or vented, except where it is unavoidably lost pursuant to § 3179.41(b).

(a) Where oil-well gas must be flared due to pipeline capacity constraints, midstream processing failures, or other similar events that prevent produced gas from being transported through the connected pipeline, the oil-well gas is “unavoidably lost” for the purposes of 43 CFR 3162.3-1(j), 43 CFR 3179.41(b)(11), and 3179.42, subject to the following limits:

(1) Flaring of 0.08 Mcf per barrel of oil produced per month between July 1, 2024 and July 1, 2025.

(2) The flaring limit of 0.07 Mcf per barrel of oil produced per month will begin on July 1, 2025.

(3) The flaring limit of 0.06 Mcf per barrel of oil produced per month will begin on July 1, 2026.

(4) The flaring limit of 0.05 Mcf per barrel of oil produced per month will begin on July 1, 2027, and remain at this level.

(b) Where substantial volumes of oil-well gas are flared the BLM may order the operator to curtail or shut-in production as necessary to avoid the undue waste of Federal or Indian gas. The BLM will not issue a shut-in or curtailment order under this paragraph unless the operator has reported flaring in excess of 1 Mcf per barrel of oil produced per month for 3 consecutive months and the BLM confirms that flaring is ongoing.

(c) If a BLM order under paragraph (b) of this section would adversely affect production of oil or gas from non-Federal and non-Indian mineral interests (e.g., production allocated to a mix of Federal, State, Indian, and private leases under a unit agreement), the BLM may issue such an order only to the extent that the BLM is authorized to regulate the rate of production under the governing unit or communitization agreement. In the absence of such authorization, the BLM will contact the State regulatory authority having jurisdiction over the oil and gas production from the non-Federal and non-Indian interests and request that that entity take appropriate action to limit the waste of gas.

(a) The operator may commingle flared gas from more than one lease, unit PA, or CA to a common high-pressure flare without BLM approval, subject to the allocation requirement in paragraph (h). The site facility diagram required under § 3173.11 must indicate that the high-pressure flare is a common, commingled flare and list the leases, unit PAs, or CAs contributing gas to the common flare.

(b) The operator must measure flared gas for high-pressure flares for volumes greater than 1,050 Mcf per month above the averaging period. For high-pressure flares measuring less than or equal to 1,050 Mcf per month over the averaging period and for low-pressure flares, operators may estimate the volume flared, as described in paragraph (h) of this section.

(c) High-pressure flares requiring measurement must use either orifice plates and orifice meter tubes, or ultrasonic meters. High-pressure flare measurement systems must meet the following requirements:

(1) Orifice metering systems must comply with the low-volume measurement requirements in § 3175.80, low-volume electronic gas measurement requirements in § 3175.100, and the low-volume gas sampling and analysis requirements in § 3175.110 with the gas sampling location requirements provided in paragraphs (d) or (e) of this section.

(2) Ultrasonic metering systems must comply with the following requirements:

(i) Each ultrasonic meter make and model must be tested for flare use. Flare gas meter testing must be conducted and reported pursuant to API 22.3 (incorporated by reference, see § 3179.30) and results must be made available to the AO upon request.

(ii) Ultrasonic meters must be installed and operated for flare use according to the manufacturer's specifications and those specifications must be provided to the AO upon request.

(iii) Ultrasonic metering systems must comply with the low-volume electronic gas measurement requirements in § 3175.100, and the low-volume gas sampling analysis requirements in § 3175.110, except for the gas sampling requirements in (d) or (e) of this section.

(3) Operators must evaluate the production facility to determine which type of flare measurement is safe for the facility.

(d) The gas sample must be taken from one of the following locations when the high-pressure flare is measuring a single lease, unit PA, or CA:

(1) At the flare meter;

(2) At the gas FMP, if there is a gas FMP at the well site and the gas composition is the same as that of the flare-meter gas; or

(3) At another location approved by the AO with a Sundry Notice submission.

(e) The gas sample must be taken from one of the following locations for a common high-pressure flare that measures more than one lease, unit PA, or CA;

(1) At the flare meter; or

(2) At another location approved by the AO with a Sundry Notice submission.

(f) Appropriate meters must be installed at all high-pressure flares pursuant to paragraph (c), and gas sampling must be taken from the appropriate location pursuant to paragraphs (d) or (e) according to the following phase-in timeline:

(g) When the flared volume for a high-pressure flare is less than or equal to 1,050 Mcf per month and for low-pressure flares, the flared volume may be estimated, or measured. Estimated flared gas volumes must be based on production reported on the ONRR OGORs over the previous 6 months and calculated at follows:

(h) If a flare is combusting gas that is combined across multiple leases, unit PAs, or CAs, the operator may measure the gas at a single point at the flare and allocate flared volumes based on the oil production while flaring from each lease, unit PA, or CA as follows:

(i) Measurement points for flared volumes are not FMPs for the purposes of subpart 3175.

(a) The operator must report all flared volumes, both avoidable and unavoidable losses, using all applicable ONRR reporting requirements.

(b) The operator must report the flared gas quality in Btu on the OGOR based on the gas analysis required in § 3179.71(d) or (e). The operator must report the same Btu content from a common flare on the OGOR for all the leases, unit PAs, or CAs contributing gas to the flare based on the gas sample analysis.

(c) Starting on September 10, 2024,operators must maintain the following records and make them available to the AO upon request:

(1) Date and time when oil or gas-well flaring begins and ends, the reason for flaring and whether the well, lease, unit PA, or CA was shut-in or returned to sales when the flaring stopped;

(2) Date and time when an emergency begins and ends, the reason for the emergency, whether the gas was vented or flared, and whether the well, lease, unit PA, or CA was shut-in or returned to sales when the emergency ended;

(3) Date and time when manual downhole liquids unloading operation or well purging begins and ends, and whether the well was shut-in or returned to sales at the end of the well maintenance.

(a) Approvals to flare royalty free, which are in effect as of the effective date of this rule, will continue in effect until November 1, 2024. After that date, the royalty-bearing status of all flaring will be determined according to the provisions of this subpart.

(b) The provisions of this subpart do not affect any determination made by the BLM before or after June 10, 2024, with respect to the royalty-bearing status of flaring that occurred prior to June 10, 2024.

(a) The hatch on an oil storage tank may be open only to the extent necessary to conduct production and measurement operations. All oil storage tanks, hatches, connections, and other access points must be vapor tight (i.e., capable of holding pressure differential at the installed pressure-relieving or vapor-recovery device's settings). Upon discovery of an oil storage tank hatch that has been left open or unlatched, and unattended, the BLM will impose an immediate assessment of $1,000 on the operator.

(b) Where practical and safe, gas released from an oil storage tank must be flared rather than vented. An operator may commingle vapors from multiple storage tanks to a single flare without prior approval from the BLM.

(a) Gas vented or flared during downhole well maintenance and well purging is royalty free for a period not to exceed 24 hours per event, provided that the requirements of paragraphs (b) through (d) of this section are met. Gas vented or flared from a plunger lift system and/or an automated well control system is royalty free, provided the requirements of paragraphs (b) and (c) of this section are met.

(b) The operator must minimize the loss of gas associated with downhole well maintenance and liquids unloading, consistent with safe operations.

(c) For wells equipped with a plunger lift system and/or an automated well control system, minimizing gas loss under paragraph (b) of this section includes optimizing the operation of the system to minimize gas losses to the extent possible, consistent with removing liquids that would inhibit proper function of the well.

(d) For any liquids unloading by manual well purging, the operator must ensure that the person conducting the well purging remains present on-site throughout the unloading to end it as soon as practical, thereby minimizing any venting to the atmosphere.

(e) For purposes of this section, “well purging” means blowing accumulated liquids out of a wellbore by reservoir pressure, whether manually or by an automatic control system that relies on real-time pressure or flow, timers, or other well data, where the gas is vented to the atmosphere. Well purging does not apply to wells equipped with a plunger lift system.

Production and processing equipment must be of sufficient size to accommodate the volumes of production expected to occur at the lease site.

(a) Pursuant to paragraph (b) of this section, the operator must maintain a BLM administrative statewide LDAR program designed to prevent the waste of Federal or Indian gas.

(b) Operators must submit a statewide LDAR program to the BLM state office with jurisdiction over the production for review. The LDAR program must cover operations and production equipment located on a Federal or Indian oil and gas lease and not operations and production equipment located on State or private tracts, even though those tracts are committed to a federally approved unit PA or CA. When there is a change of operator, the new operator must update the LDAR program on the annual update and revision timeline. Operators must submit the LDAR program in writing for review until such time as the BLM's electronic filing system is capable of receiving LDAR program submissions. At minimum, the LDAR program must contain the following information, as applicable:

(1) Identification of the leases, unit PAs, and CAs by geographic State for all States within BLM's administrative State boundaries to which the LDAR program applies;

(2) Identification of the method and frequency of leak detection inspection used at the lease, unit PA, or CA. Acceptable methods, as well as other methods approved by the BLM, and frequency include the following:

(i) Well pads with only wellheads and no production equipment or storage must include quarterly AVO inspections for leak detection;

(ii) Well pads with any production and processing equipment and oil storage must include AVO inspections every other month and quarterly optical gas imaging for leak detection; and

(iii) Other leak detection inspection methods and frequency acceptable to the BLM (e.g., continuous monitoring).

(3) Identification of the operator's recordkeeping process for leak detection and repair pursuant to § 3179.102.

(c) The BLM will review the operator's LDAR program and notify the operator if the BLM deems the program to be inadequate. The notification will explain the basis for the BLM's determination, identify the plan's inadequacies, describe any additional measures that could address the inadequacies, and provide a reasonable time frame in which the operator must submit a revised LDAR program to the BLM for review.

(d) For leases in effect on June 10, 2024, the operator must submit a statewide LDAR program to the state office no later than December 10, 2025.

(e) Operators must review and update submitted LDAR programs on an annual basis in the month in which the operator submitted the first LDAR program to ensure that the identified leases, unit PAs, and CAs, leak detection methods, and frequency of inspections are current. If the operator's LDAR program requires no changes, then the operator must notify the BLM state office that the LDAR program submitted and reviewed by the BLM remains in effect. Any updates to the LDAR program must be submitted in writing to the BLM state office for review until such time as the BLM's electronic system is capable of receiving the annual LDAR updates.

(a) The operator must repair any leak as soon as practicable, and in no event later than 30 calendar days after discovery, unless good cause exists to delay the repair for a longer period. Good cause for delay of repair exists if the repair (including replacement) is technically infeasible (including unavailability of parts that have been ordered), would require a pipeline blowdown, a compressor station shutdown, or a well shut-in, or would be unsafe to conduct during operation of the unit.

(b) If there is good cause for delaying the repair beyond 30 calendar days, the operator must notify the BLM of the cause by Sundry Notice and must complete the repair at the earliest opportunity, such as during the next compressor station shutdown, well shut-in, or pipeline blowdown. In no case will the BLM approve a delay of more than 2 years.

(c) Not later than 30 calendar days after completion of a repair, the operator must verify the effectiveness of the repair by conducting a follow-up inspection using an appropriate instrument or a soap bubble test under Section 8.3.3 of EPA Method 21—Determination of Volatile Organic Compound Leaks (40 CFR Appendix A-7 to part 60).

(d) If the repair is not effective, the operator must complete additional repairs within 15 calendar days and conduct follow-up inspections and repairs until the leak is repaired.

(a) The operator must maintain the following records for the period required under 43 CFR 3162.4-1(d) and make them available to the AO upon request:

(1) For each inspection required under § 3179.100 of this subpart, documentation of:

(i) The date of the inspection; and

(ii) The site where the inspection was conducted;

(2) The monitoring method(s) used to determine the presence of leaks;

(3) A list of leak components on which leaks were found;

(4) The date each leak was repaired; and

(5) The date and result of the follow-up inspection(s) required under § 3179.101(c).

(b) With the annual review and update of the LDAR program under § 3179.100(e) the operator must provide to the BLM state office an annual summary report on the previous year's inspection activities that includes:

(1) The number of sites inspected;

(2) The total number of leaks identified, categorized by the type of component;

(3) The total number of leaks that were not repaired from the previous LDAR program year due to good cause and an estimated date of repair for each leak.

(c) AVO checks are not required to be documented unless they find a leak requiring repair.

Certain instances of noncompliance warrant the imposition of immediate assessments upon the violation, as prescribed in the following table. Imposition of any of these assessments does not preclude other appropriate enforcement actions under other applicable regulations.

This action by the Principal Deputy Assistant Secretary is taken pursuant to an existing delegation of authority.