Fluid Mineral Leases and Leasing Process

AGENCY:

Bureau of Land Management, Interior.

ACTION:

Proposed rule.

SUMMARY:

The Bureau of Land Management (BLM) is proposing to revise the BLM's oil and gas leasing regulations. Among other things, the proposed rule would reflect provisions of the Inflation Reduction Act pertaining to royalty rates, rentals, and minimum bids, and would update the bonding requirements for leasing, development, and production. The proposed rule would also improve the BLM's leasing process to ensure proper stewardship of public lands and resources and would revise some operating requirements.

DATES:

Send your comments on this proposed rule to the BLM on or before September 22, 2023. The BLM is not obligated to consider any comments received after this date in making its decision on the final rule.

Information Collection Requirements: This proposed rule includes revised and new information-collection requirements that must be approved by the Office of Management and Budget (OMB). If you wish to comment on the information-collection requirements, please note that those comments should be sent directly to OMB. OMB is required to make a decision concerning the collection of information contained in this proposed rule between 30 and 60 days after publication of this document in the Federal Register . Therefore, a comment to the OMB on the proposed information-collection revisions is best assured of being given full consideration if the OMB receives it by September 19, 2023.

ADDRESSES:

Mail, personal, or messenger delivery: U.S. Department of the Interior, Director (630), Bureau of Land Management, 1849 C St. NW, Room 5646, Washington, DC 20240, Attention: 1004–AE80. Federal eRulemaking Portal: https://www.regulations.gov. In the Search-box, enter “RIN 1004–AE80” and click the “Search” button. Follow the instructions at this website.

For Comments on Information—Collection Activities

Information-Collection Requirements: Written comments and suggestions on the information-collection requirements should be submitted by the date specified earlier in DATES to https://www.reginfo.gov/public/do/PRAMain. Find this specific information-collection by selecting “Currently under Review—Open for Public Comments” or by using the search function.

If you submit comments on these information-collection burdens, you should provide the BLM with a copy at one of the addresses shown earlier in this section so that we can summarize all written comments and address them in the final rulemaking. Please indicate “Attention: Paperwork Reduction Act Comments (RIN 1004–AE80).” Comments not pertaining to the proposed rule's information-collection burdens should not be submitted to OMB. The BLM is not obligated to consider or include in the Administrative Record for the final rule any comments that are improperly directed to OMB.

FOR FURTHER INFORMATION CONTACT:

Peter Cowan, Senior Mineral Leasing Specialist, telephone: (720) 838–1641 or email: picowan@blm.gov, for information regarding the substance of this proposed rule or Matt Warren, Acting Division Chief for the Division of Fluid Minerals, telephone: (505) 216–8832, or email: mwarren@blm.gov, for information about the BLM's fluid minerals program. For questions relating to regulatory process issues, contact Faith Bremner at email: fbremner@blm.gov. Individuals in the United States who are deaf, blind, hard of hearing, or have a speech disability may dial 711 (TTY, TDD, or TeleBraille) to access telecommunications relay services for contacting Mr. Warren. Individuals outside the United States should use the relay services offered within their country to make international calls to the point-of-contact in the United States.

SUPPLEMENTARY INFORMATION:

I. List of Acronyms

II. Executive Summary

III. Public Comment Procedures

IV. Background

V. Discussion of the Proposed Rule

VI. Overview of Modifications

VII. Procedural Matters

I. List of Acronyms

ANWR = Arctic National Wildlife Refuge

BLM = Bureau of Land Management

CA = Communitization Agreement

CD = Certificate of Deposit

CFIUS = Committee on Foreign Investment in the United States

CFR = Code of Federal Regulations

DOI = Department of the Interior

E.O. = Executive Order

EOI = Expression of Interest

EPAct = Energy Policy Act of 2005

FLPMA = Federal Land Policy and Management Act

FOOGLRA = Federal Onshore Oil and Gas Leasing Reform Act of 1987

GAO = Government Accountability Office

IBLA = Interior Board of Land Appeals

IIJA = Infrastructure Investment and Jobs Act of 2021

IRA = Inflation Reduction Act of 2022

LOC = Letter of Credit

MLA = Mineral Leasing Act of 1920, as amended (MLA is also referred to as “Act” in the regulations.)

MLAAL = Mineral Leasing Act for Acquired Lands of 1947, as amended

MLRS = Mineral and Land Records System

NEPA = National Environmental Policy Act

NFLSS = National Fluids Lease Sale System

NPR–A = National Petroleum Reserve—Alaska

OIG = Office of the Inspector General

OMB = Office of Management and Budget

ONRR = Office of Natural Resources Revenue

OPM = Office of Personnel Management

PRA = Paperwork Reduction Act

RIA = Regulatory Impact Analysis

ROW = Right-of-way

SBA = Small Business Administration

SO = Secretarial Order

SME = Subject matter expert

U.S.C. = United States Code

USFS = United States Forest Service

II. Executive Summary

This proposed rule aims to enhance the administration of oil and gas-related activities on America's public lands and reflects provisions in recently enacted laws that modify aspects of the Federal onshore oil and gas program. Specifically, the proposed rule would implement changes pertaining to royalty rates, rentals, and minimum bids for BLM-issued oil and gas leases and would update the bonding requirements for leasing, development, and production. The BLM has not comprehensively updated the Federal onshore oil and gas program's regulatory framework since 1988. As a result, many of the program's regulatory requirements are outdated, do not adequately protect the fiscal interests of the American public, and do not promote leasing practices that are consistent with diligent development requirements and multiple-use and sustained-yield principles. This proposed rule seeks to update the existing regulations accordingly.

The Secretary of the Interior manages a Federal onshore oil and gas program pursuant to the requirements of various statutes, including the Federal Land Policy and Management Act of 1976, as amended (43 U.S.C. 1701 et seq.) (FLPMA), the Mineral Leasing Act of 1920, as amended (30 U.S.C. 181 et seq.) (MLA), and the Mineral Leasing Act for Acquired Lands of 1947, as amended (30 U.S.C. 351 et seq.) (MLAAL), as well as the recently enacted Inflation Reduction Act (IRA) of 2022 and Infrastructure Investment and Jobs Act (IIJA) of 2021. Under FLPMA, the BLM manages approximately 245 million acres of public lands and approximately 700 million acres of federally owned subsurface minerals “on the basis of multiple use and sustained yield,” which requires the BLM to achieve “a combination of balanced and diverse resource uses that takes into account the long-term needs of future generations for renewable and non-renewable resources.” The BLM is required to avoid “permanent impairment of the productivity of the land and the quality of the environment with consideration being given to the relative values of the resources and not necessarily to the combination of uses that will give the greatest economic return or the greatest unit output.” Oil and gas-related activities are one of the multiple land uses that FLPMA authorizes and which the BLM administers in accordance with the MLA and MLAAL. Both of those Acts govern the leasing of public lands to explore for and develop petroleum, natural gas, coal, and other hydrocarbons, amongst other mineral deposits.

Over the past 2 years, Congress has modified certain aspects of the Federal onshore oil and gas program through the IRA and IIJA. In the IRA, Congress updated the onshore oil and gas program's fiscal terms and established a new leasing scheme for Federal lands. In the IIJA, Congress directed the BLM to proactively “reduce the inventory of idled wells on Federal land.” Idled wells can cause a wide range of impacts on public lands, waters, wildlife, and nearby communities. There are currently thousands of idled wells on Federal lands, many of which have not produced oil or gas in years. The BLM intends to address the IRA and IIJA in this rulemaking.

Prior to the enactment of the IRA and IIJA, the Government Accountability Office (GAO) and the Department of the Interior's (DOI) Office of the Inspector General (OIG) reviewed and audited the BLM's Federal onshore oil and gas program to identify problematic areas in this program and recommended actions to address them. As part of the GAO's and OIG's respective audits, they highlighted weaknesses in the onshore program's fiscal framework and recommended that the BLM take steps to ensure that the American public receives a fair return from oil and gas activities on public lands. The DOI and the BLM concurred with these recommendations in the Report on the Federal Oil and Gas Leasing Program issued in November 2021. Accordingly, the BLM is proposing to adjust its oil and gas bonding requirements, including by increasing minimum bond amounts for the first time in decades. The BLM believes that doing so, along with other proposed changes, would help ensure that reclamation costs reside primarily with oil and gas lessees, operating rights owners, and operators and not the American public. In the same vein, the BLM is proposing to adjust its cost recovery mechanisms so that project applicants provide a more appropriate share of up-front costs. Finally, the BLM is proposing several changes to encourage diligent development of leased lands and to direct leasing to areas with fewer multiple-use conflicts and a greater likelihood of achieving responsible development.

III. Public Comment Procedures

If you wish to comment on this proposed rule, you may submit your comments to the BLM by mail, personal or messenger delivery, or through https://www.regulations.gov (see the ADDRESSES section). Please make your comments on the proposed rule as specific as possible, confine them to issues pertinent to the proposed rule, explain the reason for any changes you recommend, and include any supporting documentation. Where possible, your comments should reference the specific section or paragraph of the proposal that you are addressing. The BLM is not obligated to consider or include in the Administrative Record for the final rule any comments received after the close of the comment period (see DATES ) or comments delivered to an address other than those listed previously (see ADDRESSES ). Comments, including names and street addresses of respondents, will be available for public review at the address listed under “ ADDRESSES: Mail, personal or messenger delivery ” during regular hours (7:45 a.m. to 4:15 p.m. Eastern Time), Monday through Friday, except holidays. Before including your address, telephone number, email address, or other personal identifying information in your comment, be advised that your entire comment—including your personal identifying information—may be made publicly available at any time. While you can ask us in your comment to withhold from public review your personal identifying information, we cannot guarantee that we will be able to do so.

As explained later, this proposed rule includes revisions to information collection requirements that must be approved by the OMB. If you wish to comment on the revised information collection requirements in this proposed rule, please note that such comments must be sent directly to the OMB in the manner described in the ADDRESSES section. The OMB is required to make a decision concerning the collection of information contained in this proposed rule between 30 and 60 days after publication of this document in the Federal Register . Therefore, a comment to the OMB on the proposed information collection revisions is best assured of being given full consideration if the OMB receives it by September 19, 2023.

IV. Background

The BLM is undertaking this rulemaking for two primary reasons: (1) to reflect provisions in recently enacted laws that modify aspects of the Federal onshore oil and gas program; and (2) to enhance the administration of the onshore program, consistent with the BLM's multiple-use and sustained-yield mission. As documented in a DOI report released in November 2021, and in numerous reports from the GAO and DOI's OIG, the onshore program, historically, has failed to provide the Federal Government with a fair return; exposed the Federal Government to significant reclamation-related liabilities; lacked adequate cost recovery mechanisms; and encouraged speculative leasing and wasteful development practices. Through this rulemaking, the BLM intends to adopt new procedures and requirements to address those issues.

The Secretary of the Interior manages Federal oil and gas resources pursuant to the MLA, MLAAL, and other statutes pertaining to specific categories of lands. The MLA and MLAAL prescribe the minimum bid amounts, minimum rental rates, and minimum percentage of royalty reserved to the United States under onshore oil and gas leases on most Federal lands. The BLM is the agency within DOI responsible for regulating onshore leasing activities for federally managed lands and the subsurface mineral estate. The BLM regulations governing onshore oil and gas leasing activities are set out in 43 CFR parts 3000 and 3100. Aside from updating certain application fees for consistency, the BLM is not proposing in this rule to revise the regulations at 43 CFR part 3130, which govern oil and gas activity in the National Petroleum Reserve—Alaska.

In 1976, FLPMA established particular land and resource management authorities for the BLM, emphasizing multiple use, sustained yield, and environmental protection as the guiding principles for public land management. FLPMA directs the BLM to manage some areas for conservation, to consider the best use of public lands in a broader context than just economic return, and to take action necessary to prevent unnecessary or undue degradation of the lands.

Today, Federal onshore oil and gas production accounts for approximately 10 percent of domestically produced oil and 8 percent of domestically produced natural gas. As of the end of Fiscal Year (FY) 2022, the BLM managed 34,409 Federal oil and gas leases covering 23.7 million acres with nearly 89,350 wells that are capable of production. Of the more than 23 million onshore acres under lease today, over 11 million (approximately 48 percent) of those acres are non-producing.

A. Addressing Recently Enacted Laws Concerning the Federal Onshore Oil and Gas Program

Over the past 2 years, Congress has enacted two laws—the IRA (Pub. L. 117–169) and the IIJA (Pub. L. 117–58)—that modify the Federal onshore oil and gas program's statutory framework. Through this rulemaking, the BLM will incorporate the provisions that are contained in these Acts into its oil and gas regulations.

1. Inflation Reduction Act

In August 2022, Congress passed the IRA, two sections of which the BLM intends to implement, in part, through this rulemaking: (1) Section 50262—Mineral Leasing Act Modernization; and (2) Section 50265—Ensuring Energy Security.

Section 50262—Mineral Leasing Act Modernization

In IRA section 50262, Congress modernized the onshore oil and gas program's fiscal terms. Over the past decade, the GAO and OIG have repeatedly raised concerns about the fiscal soundness of the onshore program. Furthermore, in 2011, the GAO added the “Management of Federal Oil and Gas Resources” to its list of “high-risk” Federal programs after determining that DOI “does not have reasonable assurance that it is collecting its share of revenue from oil and gas produced on Federal lands.” “High-risk” programs are “vulnerable to waste, fraud, abuse, or mismanagement, or in need of transformation.” GAO reaffirmed this “high-risk” determination in 2021 and specifically recommended that DOI “needs to commit to developing policies that consistently lead towards improvements in . . . ensuring the government receives a fair return.”

The IRA addressed some of the GAO and OIG's concerns by increasing the onshore program's statutory royalty rate, minimum rental rates, and minimum lease bid, and establishing a new fee on expressions of interest (EOI). The BLM proposes to incorporate these statutory changes into its oil and gas regulations.

Section 50265—Ensuring Energy Security

In section 50265 of the IRA, Congress enacted new oil and gas leasing terms for Federal lands. Under these terms, the BLM “may not issue a right-of-way for wind or solar energy development on Federal land” unless it has: (1) held an onshore oil and gas lease sale during the 120-day period ending on the date of the issuance of the right-of-way; and (2) “the sum total of acres offered for lease in onshore lease sales during the 1-year period ending on the date of the issuance of the right-of-way . . . is not less than the lesser of . . . 2,000,000 acres[ ] and 50 percent of the acreage for which expressions of interest have been submitted for lease sales during that period. . . .”

2. Infrastructure Investment and Jobs Act

In November 2021, Congress passed the IIJA, which amended section 349 of the Energy Policy Act of 2005 (EPAct) (Pub. L. 109–58). Section 349 of EPAct directs the BLM to “establish a program . . . to remediate, reclaim, and close orphaned, abandoned, or idled oil and gas wells located on land administered by the land management agencies within the Department of the Interior and the Department of Agriculture.” Section 349 defines an “idled well” as “a well . . . [that] has been nonoperational for at least 7 years” and has “no anticipated beneficial use.”

Since EPAct's passage in 2005, the BLM has gained additional information, experience, and insights into its efforts to inventory and manage idled wells. In 2018, the OIG issued a report finding that “[i]dle wells pose notable financial risk to the U.S. Government and the taxpayer, as idle wells can fall into disrepair creating environmental, safety, and public health hazards. In addition, idle wells pose a risk of becoming orphaned, thus creating an undue financial burden on the taxpayer to pay for plugging and reclaiming. Idle wells have the potential to cost taxpayers millions of dollars if not properly reviewed and managed.” The OIG also identified “various program management issues,” including a “lack of an accurate inventory of idle wells” and “unreliable data in managing idle wells,” “that have contributed to BLM's inability to reduce its idle well numbers.” To address these issues, the OIG recommended that the BLM strengthen its procedures for monitoring and tracking idled wells.

The GAO also addressed the idled well program in a pair of reports issued in May 2018 and September 2019. In these reports, the GAO stated that the BLM has “few policy tools to manage shut-in wells,” which represent a “large portion” of wells that become idled and orphaned. The GAO also identified nearly 2,300 idled wells “at increased risk of becoming orphaned because they have not produced since June 2008 and have not been reclaimed.” The bonds for “a majority of these at-risk wells” were “too low to cover” their anticipated reclamation costs, which, according to the GAO, may exceed $330 million.

In the IIJA, Congress provided the BLM with additional direction concerning the idled well program. Specifically, the IIJA requires the BLM to “periodically review” and proactively “reduce the inventory of idled wells on Federal land.” The IIJA also reduces the nonoperational period after which a well is considered idled from 7 to 4 years. In light of these statutory directives, as well as the recommendations from the OIG and GAO, the BLM is proposing to adopt additional requirements for operators of nonoperational wells (specifically, shut-in and temporarily abandoned wells). The BLM believes that these requirements would help the BLM reduce its inventory of idled wells through improved identification, tracking, and proactive management.

B. Enhancing the Administration and Functioning of the Federal Onshore Oil and Gas Program

In addition to addressing recent Congressional directives, the BLM is undertaking this rulemaking for the purpose of adopting new procedures and requirements that would enhance the administration of the Federal onshore oil and gas program, consistent with the BLM's multiple use and sustained yield mission. The BLM has not updated its oil and gas regulations comprehensively since 1988 and believes that changes are needed to reduce taxpayer exposure to reclamation-related liabilities; provide adequate cost recovery mechanisms; direct oil and gas leasing to appropriate locations; and encourage diligent development by parties that are responsible and qualified to conduct such development.

1. Reducing Taxpayer Exposure to Reclamation-Related Liabilities

The MLA requires the BLM to “establish such standards as may be necessary to ensure that an adequate bond, surety, or other financial arrangement will be established prior to the commencement of surface-disturbing activities on any lease, to ensure the complete and timely reclamation of the lease tract, and the restoration of any lands or surface waters adversely affected by lease operations after the abandonment or cessation of oil and gas operations on the lease” (see 30 U.S.C. 226(g)). The MLA further requires the BLM to include in oil and gas leases “such provisions as [it] deem[s] necessary . . . for the protection of the interests of the United States . . . and for the safeguarding of the public welfare” (see 30 U.S.C. 187). To comply with these statutory requirements, the BLM is proposing to update its bonding framework for the first time in over 60 years and adopt additional changes to limit the reclamation-related liabilities of the Federal Government.

The BLM's current minimum bond amounts are outdated, expose the Federal Government to significant financial risks in the event of bankruptcies, and delay “complete and timely” reclamation and restoration of lease tracts, which can cause or exacerbate a range of environmental issues, including methane leaks, surface and groundwater contamination, interference with agricultural activities, and degraded wildlife habitat. The BLM has not increased its minimum bond amounts, which are currently $10,000 for individual lease bonds, $25,000 for statewide bonds, and $150,000 for nationwide bonds, since 1951 (statewide and nationwide bonds) and 1960 (individual lease bonds). Accounting for inflation, the 2022 equivalents of those bond amounts are $100,105, $281,399, and $1,688,394 respectively. (See https://www.usinflationcalculator.com/ ). Consequently, the BLM's current bonding requirements “may not create an incentive for operators to promptly reclaim wells after operations cease because it costs more to reclaim the wells than the operator could collect from its bond.” ⁹ According to the BLM's internal estimates, plugging costs alone typically range from $35,000 to $200,000 per well.

In addition to increasing minimum bond amounts, the BLM is proposing other measures to protect taxpayers from reclamation-related liabilities. These include enhanced oversight of idled wells, as discussed previously. The BLM also intends to streamline the process for adding noncompliant entities to its list of entities and their officers that may not receive new leases under section 17(g) of the MLA, 30 U.S.C. 226(g).

2. Providing Adequate Cost Recovery Mechanisms

As explained in greater detail in the Discussion of the Proposed Rule, the BLM is proposing to revise the onshore program's cost recovery mechanisms. The BLM is doing so to ensure that the program's application fees reflect actual processing costs. In 2021, the GAO released a report on the BLM's fee structure for the onshore oil and gas program, which stated that the “BLM does not have assurance that its current application fees reflect changes in conditions because its biennial fee review does not examine all the costs BLM intended to recover through its application fees.” The BLM concurred with that finding, and, in conjunction with this rulemaking, evaluated those costs, which informed the proposed adjustments to the onshore program's application fees.

3. Directing Oil and Gas Leasing to Appropriate Locations

To assist with the consideration and selection of lease sale parcels, the BLM intends to incorporate preference criteria into its oil and gas regulations. Historically, the BLM has not employed nationwide criteria to inform its selection of sale parcels. The BLM has invested a considerable amount of time and resources on evaluating parcels that the public does not purchase and that lessees do not develop. Between 2013 and 2022, the BLM offered approximately 40.3 million acres and leased approximately 9.5 million acres from competitive lease sales. Even when parcels sell at or above the minimum bid, they are rarely developed or generate royalties for the Federal Government. The GAO found that only about 7 percent of the leases reviewed produced oil and gas in the primary term of the lease. The BLM believes that by directing Federal oil and gas leasing towards areas that are more likely to produce, it can appropriately utilize the BLM's time and resources. When new technology becomes available, the BLM would reevaluate development potential in light of that technology, which could change the identified areas that are more likely to produce.

The lack of preference criteria to aid in the selection of sale parcels also leads to conflict when leases are offered in areas with sensitive cultural, wildlife, and recreation resources. By directing leasing toward areas that do not have such resources, the BLM believes it can proactively avoid some of these conflicts. Additionally, the BLM believes that this approach would provide stakeholders with greater certainty, as it would be understood at the outset of the leasing process that the preference criteria would guide the BLM's decision-making.

While the proposed rule text sets out a number of criteria to aid the BLM in selecting parcels for potential inclusion in lease sales, the analysis of the impacts of leasing these parcels would also address the potential impacts of direct, indirect, and cumulative greenhouse gas emissions from leasing in accordance with the National Environmental Policy Act (NEPA) and applicable legal precedent. While the preference criteria will also affect the environmental consequences of proposed leasing, the BLM requests comment on whether the preference criteria or other portions of this proposed rule should be expanded, or new provisions added, to discuss analysis of greenhouse gas emissions and related decision-making based on the analysis.

4. Encouraging Diligent Development of Federal Oil and Gas Leased Resources

The BLM has added provisions to the proposed rule that would incentivize diligent development of leased resources by responsible and qualified parties. When oil and gas leases are not diligently developed, as required by the MLA and expressly stated in the BLM's oil and gas lease form, there can be significant opportunity costs. For example, the BLM expends time and resources processing and administering lease suspensions and drilling permit extensions that often do not lead to development. Additionally, leases that are not diligently developed can limit the BLM's ability to manage public lands for other uses and resources and fulfill its multiple-use and sustained-yield missions. For these reasons, the BLM is proposing to limit the use of lease suspensions and drilling permit extensions, and, prior to issuing or approving the transfer of leases, strengthen its oversight of whether the potential transferees are responsible and qualified to pursue development.

V. Discussion of the Proposed Rule

A. Summary

The proposed modifications to parts 3000, 3100, 3110, 3120, 3130, 3140, 3150, 3160, 3170, and 3180 are described in detail in the following section-by-section discussion. In addition, minor non-substantive changes, which do not warrant detailed discussion, are also proposed throughout the rule. For example, the rule proposes to change “the Bureau” to “the BLM,” change “Service” to “ONRR,” spell out single-digit numbers, and change the question-and-answer formatting to be consistent with other regulations that appear in the CFR. Throughout the proposed rule, the existing term “shall” has been replaced with the words “must,” “will,” or “may,” as appropriate, to reduce confusion. The proposed rule would update all time frames to specify either business or calendar days in order to reduce confusion.

In addition, all sections in the parts that are being revised and replaced would be redesignated to remove the hyphens from the existing section numbers to comply with the Office of the Federal Register's updated style requirements. For example, § 3000.0–5 would be redesignated to § 3000.5. Removing the hyphens would require the BLM to redesignate some of the existing section numbers with decimals by adding more place values to them, which would allow the BLM to subsequently delineate the different sections. For example, § 3000.1 would be redesignated as § 3000.10, § 3000.2 would be redesignated as § 3000.20, and so on. This redesignation would be carried throughout the proposed rule, even in sections that are not otherwise being updated. Finally, the BLM would remove the regulatory section numbers for headings that have no text associated them. These are referred to as “undesignated center headings” and serve as section guideposts in the regulations.

Each section of each subpart, and each provision within those sections, is separate and severable from the other sections and provisions. If any provision of this rule is stayed or determined to be invalid or unenforceable, that provision shall be severable from the rest of the rule and not affect any remaining provisions. The remaining provisions would remain in force. This rule should be construed to continue to give the maximum effect to each provision as permitted by law.

B. Section-by-Section Discussion

The following discussion addresses the proposed changes to the existing regulations. If a provision is not specifically discussed in this section-by-section analysis, then the provision would be essentially the same as the existing regulation, except for the minor non-substantive changes discussed previously.

1. Section-by-Section Discussion for Changes to 43 CFR Subpart 3000

The proposed rule would add a new section to the existing subpart 3000 regulations and revise five section headings. The goal of the revisions is to replace the existing question-and-answer formats and use more commonly used terms, consistent with other changes made throughout this rule.

Section 3000.5 Definitions

The BLM is proposing to alphabetize the definitions in this section.

The proposed rule would add a definition for “acreage for which expressions of interest have been submitted” to refer to acreage that is identified in an expression of interest received by BLM, that has not been proposed for leasing in any pending sale or other expression of interest pending BLM disposition, and for which BLM may lawfully issue an oil and gas lease. This definition and the below definition of “acres offered for lease” are intended to clarify the means by which BLM will internally track its leasing progress for purposes of the Inflation Reduction Act, as further specified in new § 3120.42.

The proposed rule would add a definition for “acres offered for lease” to mean all acres that BLM has offered for oil and gas lease, regardless of whether those acres are acreage for which expressions of interest have been submitted.

The proposed rule would update the definition for “Act” to include the acronym MLA for the Mineral Leasing Act of 1920, as this acronym would appear in the proposed regulatory text.

The proposed rule would replace the term “Service” in this section with “ONRR” because the relevant functions of the prior Minerals Management Service (also referred to throughout the existing regulations as “Service”) are now performed by the ONRR. The proposed rule would likewise change the term “Service” to “ONRR” wherever it appears in the parts 3000 and 3100 regulations.

The proposed rule would add a definition for “Person” to unify the terms “person” and “entity.” The proposed definition would define “person” to mean any individual or entity, such as a partnership, association, State, political subdivision of a State or territory, or a private, public, or municipal corporation.

The proposed rule would modify the existing definition for “Proper BLM office” to remove the reference to the BLM Alaska State Office. The definition of this term would continue to refer the reader to § 1821.10, which contains the location information for all BLM state offices.

A new definition for “Properly filed” would be added to proposed § 3000.5 to correspond to the use of the term in § 3000.60. The new definition would describe “Properly filed” as a document or form submitted to the appropriate office with all necessary information and payments, as provided in 43 CFR subpart 1822.

The proposed rule would modify the existing definition for “Surface managing agency” to ensure that the definition includes other agencies within the DOI with which the BLM must coordinate, in addition to non-DOI agencies that have management responsibility for the surface resources that overlay federally owned minerals. The revised definition would replace the phrase “any Federal agency outside of the Department of the Interior with jurisdiction over the surface overlying federally owned minerals” with “any Federal agency, other than the BLM, having management responsibility for the surface resources that overlay federally owned minerals.”

Section 3000.20 False Statements

The purpose of this section is to inform the public that submitting false or fraudulent statements to the agency is a crime punishable by imprisonment or a fine, or both. The proposed rule would remove the references to specific imprisonment times and fine amounts for violations provided in 18 U.S.C. 1001. The purpose of this change is to ensure that this regulation does not become inaccurate or obsolete if the penalty provisions in 18 U.S.C. 1001 are updated. The penalties are already referenced at 18 U.S.C. 1001, which is cited in the BLM's regulation.

Section 3000.40 Appeals

A BLM decision is subject to appeal to the Interior Board of Land Appeals (IBLA) in accordance with the regulations contained in 43 CFR part 4, when a decision accomplishes, authorizes, or prohibits some action. See International Petroleum, 190 IBLA 130, 134–35 (2017). The BLM will identify the applicable authority under which it made its decision. Actions under certain sections of BLM's oil and gas leasing regulations, for example the BLM's filing fees, are not subject to appeal, because such actions are authorized pursuant to a previous notice-and-comment process. The proposed rule would add a reference to § 3000.120 to clarify that point, consistent with existing language found under § 3000.12(b), which states the amount of a fixed fee is not an agency decision subject to appeal under § 3000.40 and part 4. The BLM also proposes to also add a reference to proposed § 3000.130, which includes a similar paragraph stating the financial terms for new leases are not subject to appeal. The proposed rule would update an existing CFR reference from § 3101.7–3(b) to § 3101.53(b). This change reflects the proposed redesignation changes to the process for oil and gas lease issuances under § 3101. The proposed rule would remove a reference to § 3120.1–3, as the title and language in that section are proposed to change from “protests and appeals” to “protest” only. (See the discussion on the proposed § 3120 later in this preamble.)

Section 3000.50 Limitations On Time To Institute Suit To Challenge a Decision of the Secretary

The proposed rule would update the word “contesting” in this section to the more commonly used term “challenging” to provide clarity.

Section 3000.60 Filing of Documents

This section describes how to file documents with the BLM. The proposed rule would update this section to enable the BLM to accept electronically filed documents. The provision would still allow the use of hard-copy mailing services. In addition, this section would update the reference to § 1821.2 to the correct citation of subpart 1822.

Section 3000.90 Enforcement Actions Under 30 U.S.C. 195

This section explains that the U.S. Department of Justice is the agency responsible for enforcement actions described in section 41 of the MLA. The proposed rule would update the title and language in this section to cite 30 U.S.C. 195. The U.S. Code reference is more informative than the current reference to “provisions of section 41 of the Act.” The proposed rule would add language from 30 U.S.C. 195 to make this provision more informative.

Section 3000.100 Fees in General

The proposed rule would rename this section from “What do I need to know about fees in general?” to “Fees in general.”

Section 3000.110 Processing Fees on a Case-by-Case Basis

The proposed rule would rename this section from “When and how does BLM charge me processing fees on a case-by-case basis?” to “Processing fees on a case-by-case basis.” In addition, the BLM proposes to add “and in accordance with all other applicable laws and regulations” into paragraph (b)(1) to avoid implying that an applicant may prepare or assist in the preparation of certain NEPA documents that, under CEQ regulations, are to be prepared solely by the applicable agency.

Section 3000.120 Fee Schedule for Fixed Fees

Consistent with the IRA, the BLM has implemented a nonrefundable filing fee of $5 per acre, or fraction thereof, for EOIs. This fee is not considered a cost-recovery fee, and the monies collected are transferred to the Treasury as miscellaneous receipts (see 30 U.S.C. 191).

The proposed rule would update the existing fee for name changes, corporate mergers, or transfers to heirs and devisees to include corporate dissolutions and sheriff's deeds. The BLM accepts corporate dissolutions and sheriff's deeds to recognize the change in the ownership of interest in a lease per existing policy at H–3106–1, Transfers by Assignment, Sublease or Otherwise. The BLM processes these types of changes in the same manner as name changes, corporate mergers or transfers to heirs and devisees. Thus, these changes should also require a fixed filing fee.

The BLM is also proposing to adjust the existing oil and gas filing fees for competitive lease applications, leasing under rights-of ways, class I lease reinstatements, and geophysical exploration permits. When these fees were initially set in 2005, the BLM explained that it reserved the right to amend the fees in future rulemakings to reflect new data or other evidence that the fees did not accurately reflect reasonable costs (70 FR 41532 (July 19, 2005)). The GAO has since found that the BLM has not reviewed its application fees in response to changing conditions. See GAO–22–103968, Oil and Gas Leasing: BLM Should Update Its Guidance and Review Its Fees. The BLM concurred with GAO's findings because the cost to the BLM of its oil and gas leasing process has changed since 2005. For example, the BLM moved to online auctions in 2016, and it no longer expends resources on holding auctions because the winning bidders pay the auction company directly for auction expenses. Previously, a portion of the competitive leasing application fees was intended to recover the BLM's costs for holding in-person auctions. Conversely, the BLM proposes to include the cost related to complying with the NEPA in the filing fee for a competitive lease application; that causes an increase to the filing fee. To reflect the cost changes, the BLM is proposing to amend the fee for the following document filings or actions: competitive leasing application fee, leasing under rights-of ways, class I lease reinstatements, and geophysical exploration permits.

The BLM is proposing to include new fixed filing fees for the following Federal oil and gas actions to reimburse the BLM for its reasonable processing costs: designation of successor operator; unit agreement applications; subsurface storage agreement applications; unit agreement expansion applications; and formal lease nominations. The BLM considered proposing new fixed filing fees for Federal communitization agreements (CA), Federal participating area applications, and royalty rate reduction applications, but it ultimately declined to propose these fees due to the low value and the public benefit related to these items. Royalty rate reductions occur at the end of a lease's life and allow the operator to continue producing from the property based on reduced royalties. This gives the American public the benefit of additional production and Federal revenue without additional surface disturbance or environmental impact.

The BLM considered both case-by-case and fixed filing fees for the new fees proposed in this rule. Historically, the BLM has determined costs on a case-by-case basis for types of documents where the costs may differ significantly in each case. In this proposal, the BLM has opted to institute fixed filing fees for designation of successor operator; unit agreement applications; subsurface storage agreement applications; unit agreement expansion applications; and a formal lease nomination fee because charging processing costs on a case-by-case basis would be time consuming and would not be the most efficient use of BLM resources. Collecting cost data on a case-by-case basis for each document to be processed adds to the processing costs. The BLM decided that, for the oil and gas documents at issue, it would likely be more efficient and sufficiently reliable to set a fixed fee based on average costs and indexed to inflation. In addition, applicants benefit from knowing fees in advance.

To determine the new oil and gas fixed filing fees, the BLM followed the same method it used in 2005 to set the current fixed fees: using a weighted average rather than a simple average to determine the processing cost for each type of document. This method gives greater weight to the processing cost data from state offices with a heavy workload and, thus, more expertise in processing a particular type of document. The BLM's fluid minerals program identified the processing steps and then asked the state office subject matter experts (SMEs) to identify the appropriate job position, salary level, and time required for particular steps specified by the BLM handbooks. The fluid minerals program considered changes to the processing of each type of document since the handbooks were last updated. The BLM then calculated a direct cost for each process and adjusted to 2021 salary rates without a locality factor. The BLM's fluid minerals program spot-checked the data and sent each state office a summary of the cost data that the office had previously submitted for these types of documents, along with the BLM-wide weighted average cost for each. State offices were asked to review the cost data and report whether that data, adjusted to current filing fee amounts, remained reasonable. They were also asked to re-estimate costs if the state office found the re-examined adjusted cost data to be inaccurate. A re-examination verified that the BLM's data continued to be valid and ensured that figures, which varied significantly among offices, had not been submitted in error.

Processing Steps for the Fixed Fees

The BLM reviewed the changes in processing steps due to changes in the law, regulations, and policy to determine how processing the different fixed fee applications have changed since the BLM established the fixed filing fee in 2005. The following table summarizes the results of this review.

The fixed fee for lease renewals would be removed, as there are no longer any leases eligible for renewal. Under the MLA, any lease renewal issued on or after November 15, 1990, “continue[s] for twenty years and so long thereafter as oil and gas is produced in paying quantities.” 30 U.S.C. 188(f)(3). If a lease renewed on or after November 15, 1990, fails to produce oil and gas in paying quantities at the end of its renewal term, the lease expires with no further option of renewal.

The current $500 fee for Class II lease reinstatements is located at existing 43 CFR 3108.2–3(b)(3)(vi). The BLM considered moving the existing fee to 43 CFR 3000.120 for inclusion alongside the fixed filing fees, increasing the fee to reflect the processing costs, and then adjusting the fee annually for inflation. However, the MLA, at 30 U.S.C. 188(e), specifically states for Class II lease reinstatements that “[t]he lessee of a reinstated lease shall reimburse the Secretary for the administrative costs of reinstating the lease, but not to exceed $500.” Accordingly, the BLM proposes to leave the administrative fee of $500 in its current location at 43 CFR 3108.23(b)(3)(vi).

FLPMA Factors and Processing Fees

Section 304(b) of FLPMA lists six factors, commonly known as the “FLPMA reasonableness factors,” that the BLM must consider when deciding the amount of a reasonable processing fee. Those factors are:

(1) The BLM's actual costs to process a document not including management overhead, i.e., the processing time spent by the BLM State Directors, Deputy State Directors, and other management staff. Actual costs include (but are not limited to) time spent at the state and field office levels by SMEs who work on a specific authorization, such as a lease, and funds spent on environmental reviews, technical reviews, and analyses.

(2) The monetary value, or objective worth, of the right or privilege that the applicant seeks.

(3) The efficiency with which the BLM processes a document, i.e., minimizing of waste by carefully managing agency expenses and time.

(4) Whether any of the BLM's processing costs, for actions such as studies or data collection, benefit the general public or the Federal Government, rather than just the applicant alone.

(5) Whether the project provides any significantly tangible improvement, such as a road, or other direct service to the public. Occasionally, a negative factor, such as an adverse impact on wildlife, habitats, or surface drainage, may prevent an improvement from qualifying as a public service. Data collection that the BLM requires of an applicant for monitoring an activity is not a public service.

(6) Other relevant factors.

The BLM considered each of the FLPMA reasonableness factors for each type of document for which the BLM is proposing to adjust the existing fee or add a new fixed fee. The BLM first estimated the actual cost to process a type of document. When estimating the processing costs, the BLM determined a range based on the range of costs provided by the BLM State Offices. The BLM then considered each of the other FLPMA factors to determine if they warranted setting the fee at less than actual cost. If so, the BLM then considered whether any of the remaining factors acted as an enhancing factor that would mitigate against setting the fee at less than actual cost. Lastly, the BLM decided the amount of the fee, which cannot be more than the processing cost. For all of the fees in this proposal, this method resulted in fees set at the lower end of the BLM's processing cost.

Actual Costs

Actual costs are the sum of both direct and indirect costs. Direct costs include such things as labor, material, and equipment. The BLM estimated the direct costs by reaching out to each BLM state office and requesting an estimate of the processing time for each application based on the steps detailed in the previous table. Then using the average hourly wage, the BLM calculated the direct cost for the BLM to process the application. Indirect costs include items such as rent and overhead, excluding State Director and management overhead. For an example of how the BLM would determine the sum of direct and indirect costs, assume the measured direct cost of processing a document is $200. To estimate the indirect cost for processing that document, the BLM uses a ratio that it calculates annually. Annually, the BLM calculates the indirect cost rate, which is assessed on these fixed filing fees. Indirect costs are the overhead costs, which remain after direct costs have been computed, and may include utilities, telecommunications, information technology, space rental, and other administrative support functions. Currently that ratio is 10 to 2, or 20 percent, meaning for every $10 of direct costs there would be $2 of indirect costs. The BLM would estimate the indirect cost using the ratio and direct cost figures. In this example, since the direct cost was $200 and the ratio is 10 to 2, the indirect cost is $40. The BLM then would add the direct and indirect cost figures to arrive at the actual cost figure of $240 to process the document. This method is generally accepted in the private and public sectors.

Monetary Value of the Right or Privilege

Historically, the BLM concluded that its processing costs to prepare parcels for lease sale benefit three classes of beneficiaries: the party who requests that the parcel be included in the sale, all parties who bid on the parcel, and the successful bidder. The party who requests that a parcel be included in a lease sale benefits by influencing the selection of parcels offered. The BLM considered this benefit to be greatly outweighed by the benefit to the successful bidder who ultimately obtains the lease and can develop the minerals on the parcel. Similarly, while all bidders receive the benefit of being considered for a lease, the BLM considered this benefit to be greatly outweighed by the benefits to the successful bidder who obtains the lease. With respect to the new proposed fees for agreements, the operator benefits through economic gain if and when drilling activity occurs and through development of the lease. In addition, any benefit to the general public that would accrue from increased oil and gas availability or lower prices is considered too speculative and indirect to warrant consideration.

Monetary Value to the Applicant

The BLM did not attempt to calculate the monetary benefit to each applicant because those values are not always knowable to the BLM, and it would be inefficient to attempt to calculate them for each application or submission.

Monetary Value of the Right or Privilege Granted

To gauge the monetary value, the BLM considered the monetary value of similar rights or privileges granted to applicants historically. The BLM reviewed each type of document and compared the proposed filing fee for a given type of document with our professional judgment of the historical values of similar rights or privileges the BLM has granted. In each case, the BLM believes the value of the right or privilege is so much greater than the processing cost that a fee based on the average actual cost would not significantly affect the applicant's proposed action. This is not surprising considering that the costs pertain to documents related to the commercial development of minerals. The BLM did not reduce any fees because of this factor.

Monetary Value Change

The BLM bases its decision about the monetary value of the benefit to the applicant on the value at the time the applicant submits its application. All leases have relatively large monetary value before exploration compared with the proposed fees. The basic value of the opportunity provided by a lease to explore for minerals is shown by the willingness of applicants to pay large sums before exploration for bonus bids, for lease transfers, and for exploration activities such as drilling. Because the monetary value of the right sought in a lease is much greater than the cost of processing the lease, the BLM considers it reasonable to charge a fee equal to processing costs for all lease applications.

The Efficiency Factor

The BLM's fluid minerals program asked the state office's SMEs to provide a minimum, maximum, and average time spent on each application process. Some SMEs stated that their estimated range depended on the experience of the staff. The estimates from less experienced staff increased the amounts for the average and the high estimate for processing costs. In addition, some state offices receive fewer applications than compared with other state offices. This can increase the processing time spent for researching and processing applications when they are not frequently received in a particular office. Therefore, the BLM chose to use the lowest estimate for time spent on processing applications to create the weighted average so that applicants are not penalized for understaffed offices or offices with fewer seasoned employees.

The BLM ensured that the field offices efficiently process the documents for which fees are charged. For all of the new and existing fees, the BLM based the processing procedures on standardized steps as outlined in the BLM Handbooks and Instruction Memoranda in order to eliminate duplication and extraneous procedures. The BLM developed these detailed and measurable processing steps to be efficient.

The Public Benefit Factor

Possible public benefits from the BLM processing activities, such as studies or data collection, are also difficult to measure. For example, studies related to document processing often provide information about an area's natural resources. This is sometimes a public benefit, but the value of the information, or whether there will be a benefit at all, is not predictable. The BLM concluded that document processing for types of fixed fee documents in this rulemaking does not usually produce studies or data that significantly benefits the public. In addition, the BLM determined that for each type of document in this rulemaking, the monetary value to the applicant outweighs the possible benefit of such studies to the public. The BLM analysts used their knowledge of the historical values of such cases to make these determinations. The BLM has, therefore, decided that this factor does not warrant setting any fee in this rulemaking at less than its actual processing cost.

The Public Service Factor

A project's service to the public concerns whether the applicant's project itself, as opposed to the BLM's processing of the related documents, provides some significant direct service or benefit to the general public. FLPMA refers to this as public service. Examples include improvements, such as roads, trails, or recreation facilities. Occasionally, a negative factor, such as an adverse impact on wildlife, habitats, or surface drainage, may prevent the BLM from regarding an improvement as a public service.

The BLM reviewed exploration data shared with the government to consider whether it constitutes a public service. Applicants for geophysical exploration for the oil and gas program in Alaska are required to share with the government the mineral resource data they derive from exploration. However, that information likely would not be made public. Moreover, if the information is valuable for mineral development, the BLM expects the findings would result in oil and gas leases in that area. In that case, the monetary value of the information to the permittee would outweigh its value to the public. The BLM considered that even information that is not valuable to the permit holder for mineral development might still provide some geological or geophysical information of value to the government, which the BLM could sometimes use for some types of resource management, such as land classifications. However, because there is very little information obtained in this way and because its use is unpredictable, the potential benefits of the information to the public are too small to warrant an adjustment to the proposed fee. Finally, the operator may consider geophysical information indicating low-development potential valuable because the identification of low-development potential helps the operator avoid unprofitable development; therefore, the value to the operator outweighs any public benefit.

The projects with a proposed fixed fee do not generally provide a public service. Large projects could include road construction, but such roads are rarely open to the public or built to public safety standards. In addition, they eventually must be removed. Consequently, for fixed fee documents, the likelihood of providing such a public service is too remote and speculative to warrant charging a fee less than actual costs.

Other Factors

The BLM did not find other factors that made it reasonable to adjust fees in this proposed rulemaking.

New Proposed Oil and Gas Fixed Fees

We have rounded estimated fees down or up to the nearest $5.00, for ease of payment and administration. This is consistent with general business practices.

Annual Inflation Adjustments

The BLM is also proposing to cease publishing the annual fee adjustments in the Federal Register and the CFR. The BLM would instead post the updated table on the BLM's web page with the historical fees posted in the same location. Revised fees would be effective each year on October 1. The BLM is requesting comments on this process change.

Annual inflation adjustments would be calculated based on the percentage change in the Implicit Price Deflator for Gross Domestic Product (IPD–GDP) for the 1-year period between the fourth quarters of the previous 2 years, consistent with the 2005 Cost Recovery Rule. For example, the FY 2022 fees were set based on the change in the IPD–GDP from the fourth quarter of 2020 to the fourth quarter of 2021. The BLM would then multiply the current fee amounts by that multiplier to obtain the adjusted fee amounts. The resulting amounts would be rounded to the nearest $5 at the end of the calculation process for ease of payment and administration. This is consistent with general business practices.

Existing Applications

The BLM would not charge a new fixed fee under this rule for processing a document that the BLM received before the effective date of the rule. Documents submitted before the effective date of the final rule will be processed with the appropriate fees under the regulations existing as of the submittal date.

Section 3000.130 Fiscal Terms of New Leases

The BLM is proposing a new provision consisting of a table outlining the fiscal terms for new leases. Under the existing regulations, various subparts describe the base rental rate for leases. Likewise, various subparts describe the minimum bonus bids for competitive leases. In this rule, the BLM proposes to conform its regulations to the IRA by increasing the minimum bids and base rental rates. The BLM proposes to identify these rates in a new section and table so the rates can be regularly adjusted for inflation. The IRA precludes the adjustment of these fiscal terms until after August 16, 2032. Each of the various sections would now refer to this new section, rather than itemizing the relevant fees. The BLM proposes to include a paragraph (b) to state that these rates are not subject to appeal, since these base rates would be applied through the publication of a final rule in the Federal Register .

Consistent with 43 CFR 3000.120, the BLM is also proposing to no longer publish the annual fee adjustments in the Federal Register and the CFR. The BLM would instead post the updated table on the BLM's website before October 1 of each year. Revised fees would be effective each year on October 1. The BLM is requesting comments on this process change.

Annual inflation adjustments would be calculated based on the percentage change in the Implicit Price Deflator for Gross Domestic Product (IPD–GDP) for the 1-year period between the fourth quarters of the previous 2 years, consistent with the 2005 Cost Recovery Rule. For example, the FY 2022 fees were set based on the change in the IPD–GDP from the fourth quarter of 2020 to the fourth quarter of 2021. The BLM would then multiply the current fee amounts by that multiplier to obtain the adjusted fee amounts. The resulting amounts would be rounded to the nearest $5 at the end of the calculation process for ease of payment and administration. This is consistent with general business practices.

2. Section-by-Section Discussion for Changes to 43 CFR Subpart 3100

The proposed rule does not make any revisions to the section headings in the existing subpart 3100 regulations.

Section 3100.3 Authority

The purpose of this section is to describe lands that are subject to leasing. The proposed changes to this section were made to provide clarity and to conform the regulations to various other laws. This proposed section would remove the reference to the National Petroleum Reserve—Alaska (NPR–A) from the exceptions listed under both Public Domain and Acquired lands to reduce confusion. The NPR–A is appropriately listed under 43 CFR 3100.3(c) and would remain as lands that are subject to leasing under the Department of the Interior Appropriations Act, FY 1981 (42 U.S.C. 6508). These lands are subject to leasing under the regulations found under 43 CFR part 3130.

The proposed rule updates the exceptions for lands within the National Wilderness Preservation System to cite to 16 U.S.C. 1133. The proposed reference to the United States Code is more informative than the current reference to “section 4(d)(3) of the Wilderness Act.”

This proposed section would also add lands within Wild and Scenic Rivers to the exceptions listed under both Public Domain and Acquired lands. Subject to valid existing rights, the Wild and Scenic Rivers Act (16 U.S.C. 1280) withdraws from leasing lands within designated Wild and Scenic Rivers that constitute the bed or bank or are situated within one-quarter mile of the bank of any river designated a wild river.

This proposed rule would move the reference to lands within wildlife refuges in existing 43 CFR 3101.5–1 to the exceptions listed under both Public Domain and Acquired lands in the proposed redesignated 43 CFR 3100.3. This change would not impose new requirements. The proposed rule would remove the reference to noncompetitive lease offers, consistent with changes made by the IRA.

Currently, existing 43 CFR 3101.6 states that lands within Recreation and Public Purposes leases and patents are subject to lease under 43 CFR part 3100. The proposed rule would move that statement to § 3100.3(h) because it belongs in the list of authorities. It would not result in any substantive regulatory change.

Finally, this proposed section would add a reference to the Fish and Wildlife Coordinating Act (16 U.S.C. 661) in paragraphs (j)(1) through (3) dealing with coordination lands and refuges in Alaska. These references are currently found in the existing 43 CFR 3101.5–2(a), § 3101.5–2(b), and § 3101.5–3, but are more appropriately listed under the authority for leasing. These are not new requirements.

Section 3100.5 Definitions

The purpose of this section is to provide definitions of terms used through subpart 3100. The proposed rule would alphabetize the definitions and remove embedded definitions, so the terms are defined separately.

The proposed rule would update the definition for the term “bid” to include a specific definition corresponding to the term's use in 43 CFR 3109 as, in the BLM's experience, this has caused confusion in the past. For leases or compensatory royalty agreements issued under 43 CFR 3109, the term “bid” would mean an amount or percent of royalty or compensatory royalty that the owner or lessee must pay for the extraction of the oil and gas underlying the ROW, which is different from the bonus bids received on competitive leases.

The proposed rule would add a definition for “competitive auction,” which would mean an in-person or internet-based bidding process where leases are offered to the highest bidder. The addition of this term would help the BLM to streamline the regulations by obviating the need to use the longer phrase “oral or internet-based auction” throughout the regulations.

The proposed rule would add a new definition for the term “exception” which would mean a limited exemption, for a particular site within the leasehold, to a stipulation. The addition of this term would help to provide clarity in the regulations. The term is used in 43 CFR subpart 3101 and is further discussed later.

The proposed rule would add a new definition for the term “modification” which would mean a change to the provisions of a lease stipulation for some or all sites within the leasehold and either temporarily or for the term of the lease. The term is used in 43 CFR subpart 3101 and is further discussed later. The addition of this term would allow the BLM to incorporate existing policy into its regulations and help to provide clarity in the regulations.

The proposed rule would add a new definition for the term “oil and gas agreement” which would mean an agreement between lessees and the BLM to govern the development and allocation of production for existing leases, including, but not limited to, CAs, unit agreements, secondary recovery agreements, and gas storage agreements. The BLM would add this term to identify regulations that apply to multiple types of agreements. The term is used in the proposed rule in 43 CFR subpart 3105 and is further discussed later.

The proposed rule would update the definition for “operating right (working interest)” to include the holder's obligations under the lease. The amended rule would state, “Operating rights include the obligation to comply with the terms of the original lease, as it applies to the area or horizons for the interest acquired, including the responsibility to plug and abandon all wells that are no longer capable of producing, reclaim the lease site, and remedy environmental problems.” The update to this term would provide clarity in the regulations.

The proposed rule would update the definition for the “primary term of all other leases” to state that it means the initial term of the lease, which is set at 10 years. The change in this definition updates the outdated reference to 5-year terms for competitive leases used prior to FOOGLRA.

The proposed rule would update the definition for “record title” to include the lessee's obligations under the lease. The lessee's interest, which is also referred to as the record title, includes the obligations to perform and bear ultimate responsibility to adhere to lease terms, including requirements relating to well operations and abandonment. The update to this term would provide clarity in the regulations.

The proposed rule would add a new definition for “qualified bidder” to mean any person in compliance with the laws and regulations governing a bid. The addition of this term would provide clarity in the regulations.

The proposed rule would add a new definition for “qualified lessee” to mean any person that is compliant with the laws and regulations governing the BLM issued leases held by that person. The addition of this term would provide clarity in the regulations.

The proposed rule would add a new definition for “responsible bidder” to mean any person who has not defaulted on winning bids, is capable of fulfilling the requirements of onshore BLM oil and gas leases, and does not have a history of noncompliance with applicable statutes and regulations or the terms of a BLM-issued oil and gas lease. The term “responsible bidder” would not include persons who bid with no intention of paying a winning bid or persons who default on a winning bid. The addition of this term would provide clarity in the regulations.

The proposed rule would add a new definition for “responsible lessee” to mean any person who has not defaulted on previous winning bids, is capable of fulfilling the requirements of onshore Federal oil and gas leases, and does not have a history of noncompliance with applicable statutes or the terms of a BLM-issued oil and gas lease. The addition of this term would provide clarity in the regulations.

The proposed rule would add a new definition for the term “waiver” which would mean a permanent exemption from a lease stipulation. The term is used in subpart 3101 and is further discussed later. The addition of this term would allow the BLM to incorporate existing policy into its regulations and help to provide clarity in the regulations.

Finally, the BLM split out the definitions for “assignment” and “sublease” from the current definition of “transfer” in the existing regulations. This will assist the public in finding the applicable definition as well as highlight the differences between an assignment and a sublease.

Section 3100.9 Information Collection

The current regulation lists out-of-date OMB control numbers for information collection requirements. The proposed rule would update those control numbers and restructure the format of this section to include the authority for and purpose of the section, including a table that lists the current OMB control numbers.

Section 3100.31 Enforceability

The proposed rule would streamline the section on options. The MLA expressly authorizes and restricts options to acquire an interest in a lease. See30 U.S.C. 184(d). While the BLM has not previously received option statements from the industry, the BLM cannot prohibit options and will continue to accept option statements for the record if they are submitted to the BLM. Under the “Enforceability” section (43 CFR 3100.31(a)), the BLM would remove the phrase “without the approval of the Secretary.” That would eliminate the discretion to authorize options for a period of more than 3 years. Paragraph (b)(3) would be revised for clarity to change the reference to “the number of acres covered by the option and of the interests and obligations of the parties to the option, including the date and expiration date of the option” to read “the number of acres and the type and percentage of interest to be conveyed and retained by the parties to the option, including the expiration date of the option.”

Section 3100.40 Public Availability of Information

The proposed rule would not make any substantive changes to this section; however, the BLM is considering adding language that would provide notice that names and addresses of the nominator, lessee, operating rights holders, and operators would be made public through the BLM's automated system. The BLM's lease and agreement case files are already public records, and any change to this section would merely reflect the BLM's current practice.

3. Section-by-Section Discussion for Changes to 43 CFR Subpart 3101

The proposed rule would remove 10 sections in the existing subpart 3101 as outlined in Section VI of this preamble titled Overview of Modifications. The removal of these sections would cause some of the sections to be redesignated accordingly. The purpose of this removing and redesignating is to achieve consistency and ease of reference throughout subpart 3101, as sections were consolidated and reorganized.

Section 3101.12 Surface Use Rights

This section was promulgated in 1988 to clarify the BLM's authority to use the terms and conditions of the standard lease form to control site-specific environmental impacts on leaseholds, as opposed to lease-specific protective measures, addressed in lease stipulations, to mitigate impacts to specific resources values identified on leased lands. The standard lease form authorizes the BLM to require “reasonable measures” to the extent that such measures would be consistent with the lessee's rights. However, this revised section would more clearly outline the measures that the BLM may require to promote development practices that are consistent with multiple use and sustained yield and the terms of the BLM's oil and gas leases.

Specifically, this section would be updated to state that the authorized officer may require and detail reasonable measures to avoid, minimize, or mitigate adverse impacts to other resource values, land uses or users, federally recognized Tribes, and underserved communities. Such reasonable measures may include, but are not limited to, relocation or modification to siting or design of facilities, timing of operations, specification of interim and final reclamation measures, and specification of rates of development and production in the public interest. These measures are consistent with the BLM's standard lease form, which has been in effect since October 2008 and which states that the BLM “reserves [the] right to specify rates of development and production in the public interest. . . .” Additionally, the MLA authorizes the BLM to adopt “such other provisions as [it] may deem necessary . . . for the protection of the interests of the United States . . . and for the safeguarding of the public welfare.” 30 U.S.C. 187. The BLM may also manage the manner of development under this section, which may include waste prevention measures, containment of fluids, and monitoring both water and air quality in the project area. As set out in E.O. 14035, “[t]he term `underserved communities' refers to populations sharing a particular characteristic, as well as geographic communities, who have been systematically denied a full opportunity to participate in aspects of economic, social, and civic life.” E.O. 14008 provides additional guidance on securing environmental justice by requiring agencies to “[develop] programs, policies, and activities to address the disproportionately high and adverse human health, environmental, climate-related and other cumulative impacts on disadvantaged communities, as well as the accompanying economic challenges of such impacts.” For the purposes of E.O. 14008, the Council on Environmental Quality has provided interim guidance on the definition of community to “mean either a group of individuals living in geographic proximity to one another, or a geographically dispersed set of individuals (such as migrant workers or Native Americans), where either type of group experiences common conditions.” These underserved communities can be impacted as a result of greater vulnerability to environmental hazards, lack of opportunity for public participation, or other factors. Increased vulnerability may be attributable to an accumulation of negative or lack of positive environmental, health, economic, or social conditions within these populations or places. The term describes situations where multiple factors, including both environmental and socio-economic stressors, may act cumulatively to affect health and the environment and contribute to persistent environmental health disparities.

Due to the advances in horizontal and directional drilling, and in an effort to strike the best multiple use balance, the BLM proposes to update the following language: “At a minimum, measures shall be deemed consistent with lease rights granted, provided that they do not: require relocation of proposed operations by more than 200 meters; require that operations be sited off the leasehold; or prohibit new surface-disturbing operations for a period in excess of 60 days in any lease year.” The proposed language would state, “Modifications that are consistent with lease rights include, but are not limited to: requiring relocation of proposed operations by more than 800 meters and prohibiting new surface disturbing operations for a period of 90 days in any lease year.” With the changes in technology allowing 3-mile laterals and 1/2 -mile directional wells, the BLM considers 800 meters (approximately 1/2 mile) to be a reasonable floor for moving operations due to resource concerns. The BLM proposes updating the floor to account for changes in technology.

The BLM also proposes these changes because the existing provision has been misconstrued as limiting BLM's authority to require relocation only up to 200 meters. The IBLA has upheld the BLM's authority to move operations and confirmed that the siting and timing parameters in the current regulations are minimums. The BLM has the authority to impose measures higher than those in the regulations as long as they “constitute [ ] reasonable measure[s] to minimize adverse impacts under 43 CFR 3101.1–2.” Yates Petroleum, 176 IBLA 144, 156 (2008). The BLM is requesting comments on the proposed distance standard for reasonable measures.

Section 3101.13 Stipulations and Information Notices

The proposed rule would split the existing content of this section into two paragraphs for clarity and would add a new paragraph (a) to state that, when developing stipulations, the BLM would consider the sensitivity and importance of potentially affected resources and any uncertainty concerning the present or future condition of those resources. The BLM is proposing this change to more explicitly recognize its mandate to manage the Federal lands for multiple use and to provide for the protection of the resources on those lands. When evaluating stipulations to be included in a lease, the BLM will assess whether a resource is adequately protected by stipulation without regard to the restrictiveness of the stipulation on operations.

The proposed rule also would update the existing content of this section (paragraph (b)) to reflect the IRA's elimination of the noncompetitive leasing process. Paragraph (b) refers to lease stipulations, and paragraph (c) refers to lease information notices. No other substantive changes have been made to the language that now constitutes these two paragraphs. In addition, the BLM proposes to move the language and requirements from the existing regulation found at § 3101.5–4 (which refers to stipulations applied to leases for lands managed by the Fish and Wildlife Service) to a new paragraph (d) under this section to consolidate all stipulation requirements in one section.

Section 3101.14 Modification, Waiver, or Exception

The proposed rule would update the title of this section from “Modification or waiver of lease terms and stipulations” to “Modification, waiver, or exception.” The first paragraph in this section describes the standards the BLM will use when evaluating modifications, waivers, or exceptions. It states that a public review period will be required when a change to a lease term or stipulation is substantial or involves a major concern to the public.

In paragraph (a), the proposed rule proposes to add the existing modification, waiver, or exception policy for lease stipulations into the regulations based on Instruction Memorandum Number 2022–003, Documentation and Tracking Requirements for Waivers, Exceptions, and Modifications for Fluid Minerals Exploration and Development Activities. Unlike the existing policy, the BLM is proposing to remove the provision that allows the BLM to grant modifications, waivers, or exceptions (MWEs) to lease stipulations if the authorized officer determines that the “proposed operations would not cause unacceptable impacts.” This very subjective standard has been overused at times and has led to unnecessary adverse environmental impacts in some instances. The BLM would consider a change to the lease terms to be substantial if the change would have an important, considerable, consequential, major, or meaningful effect on the environment that was not previously considered, thus requiring public notification (30-day public review) of a lease term or stipulation.

In paragraphs (b) and (c), the proposed rule would split an existing provision in the regulations related to modifications of stipulations into two provisions, one of which would address modifications made before lease issuance and the other of which would address modifications made after lease issuance. This regulatory change reflects decisions of the IBLA, which have stated that if a lease is issued without prior notice of an additional stipulation, the stipulation is not binding on the potential lessee and is without effect in the absence of the potential lessee's acceptance of the stipulation. See Emery Energy, Inc, 64 IBLA 175 (1982). For modifications to stipulations prior to lease issuance, the BLM proposes to add language clarifying that the potential lessee must be given an opportunity to accept the additional or modified stipulation. If the potential lessee does not accept the additional or modified stipulation, the BLM may reject the bid and include the lands in the next Notice of Competitive Lease Sale. If the modification in stipulation(s) increases the value of the parcel, the BLM, following current policy, will reject the bid and include the lands in the next Notice of Competitive Lease Sale. For example, if the lease is currently subject to a no-surface-occupancy stipulation, and the BLM determines a controlled-surface-use stipulation is appropriate instead, this could increase the value of the lease. After lease issuance, if the BLM adds or modifies a stipulation without notice to the lessee, the additional or modified stipulation is not binding on the lessee and is without effect in the absence of the lessee's acceptance of the stipulation. When a stipulation is required by the relevant Resource Management Plan and the BLM inadvertently omits it, a lessee's failure to sign and accept modifications to the stipulations when requested by the authorized officer may subject the lease to cancellation.

Section 3101.22 Acquired Lands

For clarity, the BLM proposes to repeat the language found in the existing 43 CFR 3101.2–1(a) for public domain lands to describe the same acreage limitations that also apply to acquired lands.

Section 3101.23 Excepted Acreage

The proposed rule would update the existing 43 CFR 3101.2–3(a)(1) to change the language from “unit or cooperative plan or communitization agreement” to read “oil and gas agreement.” Under this proposed rule, unit agreements and CAs would no longer be referred to as cooperative plans and, as discussed earlier in this preamble, a new definition would be added to define “oil and gas agreements,” which includes unit agreements and CAs. In addition, the BLM has noticed that the phrase “operating, drilling, or development contract” in the existing 43 CFR 3101.2–3(a)(3) has often been confused with approved Applications for Permit to Drill. A reference to 43 CFR 3105.30 would be added to this section to clarify the phrase since “operating, drilling, or development contract” has a specific regulatory meaning.

Section 3101.25 Computation

The proposed rule would remove as outdated all language referencing an entity's ownership in a company, parties to a contract, and acreage held in common by the same persons. In 1982, the BLM eliminated the requirement to submit documents related to qualifications and now requires entities to certify their compliance with law on the lease or assignment application, subject to the criminal sanctions in 18 U.S.C. 1001 (see 47 FR 8544, February 28, 1982). Accordingly, the BLM no longer keeps documents related to qualifications and does not collect information on stock ownership, company or corporate structures (resolutions or company formation documents), or ownership in a company.

Section 3101.2–6 Showing Required

As explained in the previous section, the BLM eliminated qualification statements in 1982. The proposed rule would remove this section in its entirety, as it is outdated and no longer necessary. The BLM can run reports through its Mineral and Lands Record System to obtain the data confirming compliance with acreage limitations. When an entity exceeds its acreage limitation, the BLM provides the company with a list of the entity's leases for a particular State and provides the entity with an appropriate timeframe to identify inconsistencies or to relinquish, transfer, or otherwise divest sufficient interests before the BLM takes appropriate action to cancel the entity's excessive leases or interests.

Section 3101.30 Leases Within Unit Areas, Joinder Evidence Required

It is the policy of the BLM not to include lands that are partly within and partly outside the boundary of an oil and gas agreement in any one parcel listed in a Notice of Competitive Lease Sale. The proposed rule would remove 43 CFR 3101.3–2, “Separate Leases to Issue,” in its entirety due to the elimination of noncompetitive offers from the IRA. Incorporating this change, the heading of 43 CFR 3101.30 would now read, “Leases within unit areas, joinder evidence required.” In the remaining language regarding joinder evidence, the BLM proposes to change the term “operator” to “lessee” because this section is referring to the time of lease issuance.

Section 3101.40 Terminated Leases

The proposed rule would remove the existing 43 CFR 3101.4, “Lands Covered by Application to Close Lands to Mineral Leasing” in its entirety, since this section only applies to noncompetitive leases, which the IRA eliminated. Section 3101.40 would now be referred to as “Terminated leases.” The BLM proposes to move the content of the existing regulations at 43 CFR 3108.2–2(d) and 43 CFR 3108.2–3(c) to this section to consolidate the requirements for issuing a lease for previously leased lands that have terminated.

Section 3101.5–1 Wildlife Refuge Lands (Existing Rule)

The BLM proposes to move the content of this existing section to the Authority for leasing section (43 CFR 3100.3), for ease of reference. The BLM proposes to move paragraph (a) and the first sentence of paragraph (b), which refer to lands subject to leasing, to the Authority for leasing section at 43 CFR 3100.3(b)(2)(xiv). The BLM proposes to move the remaining language in paragraph (b) to 43 CFR 3101.52(d), to consolidate it with the regulations addressing consent from other Federal agencies.

Section 3101.5–2 Coordination Lands (Existing Rule)

The BLM proposes to move the content of this existing section to the Authority for leasing section (43 CFR 3100.03) for ease of reference.

Section 3101.53 Alaska Wildlife Areas (Existing Rule)

The BLM proposes to move the content of this existing section to the Authority for leasing section (43 CFR 3100.3(k)) for ease of reference.

Section 3101.5–4 Stipulations (Existing Rule)

The BLM proposes to move the content of this existing section, which refers to stipulations prescribed by the Fish and Wildlife Service, to the general stipulations section (43 CFR 3101.13) for ease of reference.

Section 3101.6 Recreation and Public Purposes Lands (Existing Rule)

The BLM proposes to move the content of this existing section, which refers to lands subject to leasing, to the Authority for leasing section (43 CFR 3100.3(i)) for ease of reference.

Section 3101.50 Federal Lands Administered by an Agency Outside of the Department of the Interior

The proposed rule would redesignate this section from 43 CFR 3101.7 to 43 CFR 3101.50 because of the consolidation and reorganization of neighboring sections.

Section 3101.51 General Requirements

The proposed rule would consolidate the three paragraphs under this existing section into one paragraph. Currently, there are separate paragraphs for (a) Acquired lands, (b) Public Domain lands, and (c) National Forest System lands. The new paragraph would provide that all lands will be leased only with the consent of the surface managing agency and that the surface management agency will report to the BLM whether it consents to leasing with stipulations, or, alternately, withholds consent or objects to leasing. On acquired lands, National Forest System lands, and public lands reserved for the use of the Department of Defense, the consent of the surface management agency is statutorily required prior to offering the lands for oil and gas lease. The surface management agency has the authority to refuse to consent to lease. Pursuant to longstanding BLM policy, public domain lands withdrawn or reserved for the use of another agency will be leased only after consultation with the surface management agency or upon recommendation for leasing by the surface management agency. The BLM deems a surface management agency's recommendation to not lease to have the same effect as the agency withholding consent or objecting to leasing. Regardless of whether the lands are acquired or public domain lands, the BLM will not lease lands when a surface management agency objects to leasing or withholds its consent. Consolidating these paragraphs would reduce any confusion. When an agency has given its consent to leasing, the BLM incorporates all the stipulations provided by the agency for a lease parcel. The BLM may add its own stipulations to the lease parcel. The Secretary of the Interior has the final authority and discretion to decide to offer and issue a lease. Therefore, although an agency agrees that the lands may be leased, the BLM has the authority, on behalf of the Secretary, to not issue a lease for all or a portion of the lands.

Section 3101.52 Action by the Bureau of Land Management

The proposed rule would update paragraph (b) to remove the phrase “and shall reject any lease offer,” because the IRA, by eliminating noncompetitive leasing, eliminated such offers. For ease of reference, the proposed rule would add a paragraph (d) from language now found at 43 CFR 3101.5–1(b), which references the consent required for lands managed by the Fish and Wildlife Service. The proposed rule would also remove from paragraph (d) the phrase “on a form approved by the director,” as there is no such standard form for stipulations.

4. Section-by-Section Discussion for Changes to 43 CFR Subpart 3102

The proposed rule would revise one section heading in the existing subpart 3102. The purpose of this revision is to replace outdated terminology.

Section 3102.20 Non-U.S. Citizens

The BLM proposes to rename the section on “aliens” and to replace this outdated, derogatory terminology with the phrase “non-U.S. citizens” in both the heading of the section and the language used in the paragraph. The BLM proposes to add a new paragraph (b) due to a final rule from the Office of Investment Security, Department of the Treasury, implementing the provisions relating to real estate transactions in section 721 of the Defense Production Act of 1950, as amended by the Foreign Investment Risk Review Modernization Act of 2018. That final rule was published at 85 FR 3158 (Jan. 17, 2020) and codified at 31 CFR part 802. The rule sets forth the process relating to the national security review by the Committee on Foreign Investment in the United States (CFIUS) of certain transactions, referred to in the rule as “covered real estate transactions,” that involve the purchase or lease (including an assignment or other transfer) by, or concession to, a foreign person of certain real estate in the United States. Covered real estate transactions may include certain transactions involving the Federal mineral estate. The CFIUS looks not only at the entities that are lessees, but also to any (legal) person with the ability to exercise control, as defined by the regulations of the Department of Treasury's implementing regulations, over the lessee. The CFIUS review could result in the modification, suspension, or prohibition of the acquisition of a lease or interest therein. Accordingly, the BLM recommends that each potential bidder, lessee, or other interest holder review the regulations at 31 CFR part 802 before bidding on or acquiring an interest in a Federal oil and gas lease.

Section 3102.40 Signatures

The BLM proposes to add a new introductory paragraph to clarify that this section applies to signatures on all applications and forms. When applicants submit a form or application to the BLM, they are certifying their acceptance of lease terms and stipulations, as well as their compliance with the regulations under subpart 3100. The BLM may, in its discretion, accept electronic signatures and submissions. Paragraph (a) would be updated to include that when copies of the BLM-approved forms are submitted to the BLM, they must be exact reproductions without additions, omissions, or other changes. The existing paragraph (b), referring to assignments and transfers, would be removed from this section since this language is already covered in the existing 43 CFR 3106.4–1. The existing paragraph (d), which refers to qualification numbers, would be removed as obsolete: the BLM discarded qualification statements in favor of self-certifications in 1982.

Section 3102.51 Compliance

The proposed rule would revise the introductory paragraph to more clearly define the qualifications to hold interest in a lease. The BLM proposes to update paragraph (a) to change the term “alien stockholders” to “non-U.S. citizens who own stock” for consistency with the changes described earlier. Paragraph (d) would be updated to remove the sentence, “The term entity is defined at 43 CFR 3400.0–5(rr) of this title,” because the proposed rule would add a new definition for “person,” which would include “entities” as explained earlier in 43 CFR 3000.5. Paragraphs (d), (e), and (f) would be updated to include the appropriate references to the United States Code, which are more meaningful than “sections 2(a)(2)(A) of the Act,” “section 41 of the Act,” “section 17(g) of the Act,” and “section 30A of the Act.”

In addition, the BLM proposes to revise paragraph (f) to emphasize that reclamation obligations reside primarily with oil and gas lessees, operating rights owners, and operators and not the American public and to ensure that those who are in non-compliance with section 17(g) of the MLA are not qualified to hold a lease. The BLM reviewed the timeframe it takes to add a person to the list of persons in noncompliance with MLA section 17(g). Under the current policy, it takes a minimum of 100 days from the date when the BLM first issues an incident of noncompliance (INC), or 130 days from the date when the BLM first issues a written order, due to the time it takes to complete each enforcement action. The timeframe to complete each enforcement action is generally as follows:

• Written Order (30 days)
• First INC (30 days)
• Second INC (30 days)
• Impose civil penalties (40 days)

Therefore, the BLM proposes to modify paragraph (f) and specify that noncompliance with MLA section 17(g) begins when a person has failed to comply with their reclamation obligations in the time specified by notice from the BLM, not, as under the current regulations, when the authorized officer has imposed a civil penalty or collected a bond, whichever is first. The new language would more closely track the language of the MLA at 30 U.S.C. 226(g) and would recognize the changes that were made in 2016 to 43 CFR 3163.1 and 3163.2 (81 FR 81609, Nov. 17, 2016) regarding notice of noncompliance. This language clearly states that a person's failure to timely comply with a notice of noncompliance with reclamation requirements or other standards would trigger the noncompliance with section 17(g); it would not rely on a specific follow-up action (assessment, civil penalty, or bond collection) by the BLM. This would allow the BLM flexibility in how it responds to a person's failure to comply, while clearly stating when noncompliance with section 17(g) begins.

With the regulations matching the law, the BLM would expect to quickly identify persons in noncompliance and prevent these persons from acquiring future Federal leases. The BLM would add a person to the list of persons in noncompliance with MLA section 17(g) after the abatement date has passed for the first enforcement action, either a written order or the first INC. This would result in a person being added to the 17(g) list in a minimum of 30 days, instead of the current minimum of 100 or 130 days.

Finally, the BLM proposes to add a new paragraph (h) to state that, in accordance with 2 CFR parts 180 and 1400, compliance means that the lessee, potential lessee, and all parties described at the beginning of the section are not excluded or disqualified from participating in a transaction covered by Federal non-procurement debarment and suspension, unless the DOI explicitly approves an exception for a transaction pursuant to the regulations in those parts.

Section 3102.52 Certification of Compliance

The BLM proposes to update the last sentence of this paragraph to remove the phrase “an offer,” because the IRA, by eliminating noncompetitive leasing, eliminated such offers.

5. Section-by-Section Discussion for Changes to 43 CFR Subpart 3103

The proposed rule would revise one section heading and remove two others in the existing 43 CFR subpart 3103 regulations, necessitating redesignating throughout the subpart.

Section 3103.11 Form of Remittance

The BLM proposes to update the existing paragraph by changing the reference from the Minerals Management Service to the successor agency, the ONRR.

Section 3103.12 Where Remittance Is Submitted

The proposed rule would rename this section from “Where submitted” to “Where remittance is submitted.” The BLM proposes to update paragraph (a)(1) to clarify that the processing fees for various applications would be found in the fee schedule in 43 CFR 3000.120. The BLM proposes to update paragraph (a)(2) to replace the ONRR's mailing address and direct rental payments to the ONRR's online rental payment system to conform to ONRR's regulations at 30 CFR 1218.51. The BLM proposes to update paragraph (b) to replace the phrase “communitized leases in producing well units” with the more commonly used language of “communitized leases in producing spacing units.” In addition, the BLM proposes to remove the phrase “and easements for directional drilling,” as this is an outdated reference, and the BLM has never issued easements for directional drilling.

Section 3103.21 Rental Requirements

The proposed rule would update paragraph (a) to remove the phrases “or competitive nomination” and “List of Lands Available for Competitive Nominations or” consistent with the changes made to 43 CFR part 3120. The proposed rule would also remove the reference to noncompetitive lease offers, the phrase “if known, and, if not known, shall be based on 40 acres for each smallest legal subdivision,” as well as the last two sentences in their entirety, because the IRA ended noncompetitive leasing. The proposed rule would update paragraph (b) in this section to remove the phrase “List of Lands Available for Competitive Nominations or a” due to modifications made to 43 CFR part 3120 to make nominations nonbinding.

Diligent Development

The BLM is considering adding a new requirement for diligent development obligations under Federal oil and gas leases and is particularly interested in receiving comments on this topic. As stated in the DOI's Report on the Federal Oil and Gas Leasing Program, dated November 2021, noncompetitive leases are frequently less developed than competitive leases. Similarly, the GAO reported (see GAO 22–103968 and GAO 21–138) that competitive leases with higher bonus bids were more likely to produce than competitive leases with lower bonus bids or noncompetitive leases. Accordingly, the BLM is considering adding a section to further promote development of leases by specifying the steps that must be taken to meet diligent development obligations. For example, the lessee would meet the diligent development obligation if, at the end of the fifth year of the lease term, the lessee: (a) has established actual production in paying quantities on the lease; (b) has established allocated production in paying quantities on the lease; (c) has filed a complete Application for Permit to Drill; (d) has extended the lease term by committing it to an oil and gas agreement, 43 CFR 3107.30; (e) has filed a Notice of Intent to undertake geophysical exploration. The BLM reviewed existing leases and the development milestones on those leases and determined that 56 percent of the current leases have met the proposed diligent development obligation under one of the options set out here prior to the fifth lease year.

In addition, the BLM is considering requiring the lessee to provide notice to the BLM of how and when the lessee met the diligent development obligation, and a provision increasing the rent if the lessee has not satisfied the diligent development obligation by the end of the fifth lease year. Under this provision, the lease would be subject to a supplemental escalating rental rate of an additional $1 per acre, or fraction thereof, for each lease year between the sixth and tenth lease years until the diligent development obligation is met. The BLM solicits comments as to whether the increased rental rates prescribed by the IRA may render a diligent development obligation unnecessary.

Section 3103.22 Annual Rental Payments

This section provides information on the royalty rate for existing and future leases. The proposed rule would revise the phrase “timely payment” in the introductory paragraph to “payment on or before the lease anniversary date” to more clearly specify what constitutes a timely payment. The proposed rule would update paragraph (a) to simply state that the annual rental for all leases is as stated in the lease.

To implement the IRA, for all new oil and gas leases issued in the next 10 years, rentals are set at $3 per acre, or fraction thereof, for lease years 1 and 2; $5 per acre, or fraction thereof, for years 3 through 8; and $15 per acre, or fraction thereof, thereafter. After 10 years following the enactment of the IRA, those rental rates become minimums and are subject to increase. Paragraph (b) reflects that following the commencement of production, the rental requirement converts to a minimum royalty in lieu of rental. The minimum royalty is “not less than the rental which otherwise would be required for that lease year” when production begins in paying quantities. (See § 3103.32(a)(2)).

The proposed rule would revise paragraph (b) because the existing paragraph (b) is obsolete. The proposed rule would eliminate the existing introductory paragraph (b). The proposed rule would remove the existing paragraph (d) because, due to the IRA's amendment of the MLA, reinstatements will no longer be available for noncompetitive leases issued for public domain lands. The proposed paragraph (c) would now state the annual rental for a reinstated lease is located in 43 CFR 3000.130. As required by the IRA, the rental rate for reinstated competitive leases is $20 per acre, or fraction thereof. The proposed rule would redesignate the existing paragraph (f) to paragraph (d) to state that each succeeding time a specific lease is reinstated, the rental rate will increase by an additional $10 per acre, or fraction thereof, as required by the IRA.

Section 3103.31 Royalty on Production

All updates to this section would implement provisions of the IRA. The proposed rule would update paragraph (a)(1) to state that leases issued before the passage of the IRA will have a rate as prescribed in the lease or applicable regulations at the time of lease issuance. In paragraph (a)(2), the proposed rule would increase the royalty rates for leases issued on or after the effective date of the IRA and for the next 10 years to 16.67 percent. Paragraph (a)(3) would be updated to state that for leases issued after the 10-year period following the passage of the IRA, the royalty rate will be not less than 16.67 percent. The proposed paragraph (a)(4) would state that ROW leases issued under subpart 3109 would have a minimum royalty rate of 16.67 percent.

The proposed paragraph (a)(5) would be updated to state that for reinstated leases, the royalty rate is the rate used for royalty determination that applies to new leases at the time of the reinstatement plus 4 percentage points, plus an additional 2 percentage points for each succeeding reinstatement. In no case will the reinstated lease have royalties at a rate less than 20 percent. The IRA amended the MLA to state that competitive leases may be reinstated under a condition that “a requirement for future royalties at a rate of not less than 20 percent computed on a sliding scale based upon the average production per well per day, at a rate which shall be not less than 4 percentage points greater than the competitive royalty schedule then in force [ i.e., at the time of the lease] and used for royalty determination for competitive leases issued pursuant to such section, as determined by the Secretary.” (30 U.S.C. 188(e)(3)). To implement this provision of the IRA, the reinstatement of a terminated lease with a royalty rate of 12.5 percent would be conditioned on a reinstated royalty rate of not less than 20 percent. Leases issued after the enactment of the IRA that carry a royalty rate of 16.67 percent royalty would be conditioned on a reinstated royalty rate of not less than 4 percentage points greater than the competitive royalty schedule in force at the time of the lease, or 20.67 percent. The current regulation increases the royalty rate 2 percentage points for each succeeding reinstatement. This language would remain in the regulation.

Section 3103.32 Minimum Royalties

The proposed rule would revise the exception clause in paragraph (a) by changing “except that on unitized leases” to “except on unitized leases that lack production.” This change clarifies the intended exception without suggesting that rental should be paid on the leased area outside the participating area, even when the producing well for the participating area is located on the leasehold. In general, once oil and/or gas is discovered in paying quantities on the lands committed to a unit, all lands included in the participating area are charged a minimum royalty per acre per year in lieu of rental. Rental for those portions of unitized leases that are not within such participating areas continue at the rental rate established in the lease. That is, the portion of a lease inside the participating area will pay minimum royalty and the portion outside the participating area is subject to rental. However, if there is actual production on a unitized lease, then minimum royalty should apply to the entire lease ( i.e., both portions within and outside the participating area). The proposed changes clarify that for leases partly inside and partly outside the participating area and containing a producing well (or a well that was once capable of production in paying quantities), the entire lease is obligated to pay minimum royalty.

Paragraph (a)(2) would be updated to change “competitive leases issued from successful bids placed at oral or internet-based auctions conducted after December 22, 1987” to read “competitive leases issued after December 22, 1987.” The extra language was necessary to implement changes from FOOGLRA in 1987, but it no longer applies, since the BLM does not have pending competitive lease applications that date back to 1987.

Paragraph (d) would be updated to remove the reference to 43 CFR 3108.2–4, since the section for Class III reinstatements would be eliminated, as further described in the discussion of subpart 3108.

The proposed rule would add a new paragraph (e) to state that if the royalty paid during any year aggregates to less than the minimum royalty, then the lessee must pay the difference at the end of the lease year. This is not a new requirement or a change in the BLM's policy; it is only added to clarify the pre-existing requirement.

Section 3103.41 Royalty Reductions

The proposed rule would revise paragraph (a) to change the phrase “successfully operated” to “produced in paying quantities,” which has a clearly understood meaning within the oil and gas industry. This change is to clarify the prerequisite for obtaining this relief as the previous term “successfully operated” is not a term that is easily defined.

The BLM considered additional changes to this section due to the GAO's report entitled, “Federal Oil and Gas Revenue: Actions Needed to Improve BLM's Royalty Relief Policy” GAO–21–169T. In this report, the GAO found that the BLM's decisions to grant royalty relief during the COVID–19 pandemic were not made efficiently and equitably across the states. The BLM considered using the Bureau of Ocean Energy Management (BOEM) regulations and policy on royalty rate reductions. The BOEM has multiple authorities to provide royalty relief. The BOEM regulations include the authority to grant royalty relief for deep water leases and for development and expansion projects (see 30 CFR 203.60 to 203.80), drilling ultra-deep wells on leases not subject to deep water royalty relief (see 30 CFR 203.30 to 203.36), drilling deep gas wells on leases not subject to deep water royalty relief (see 30 CFR 203.40 to 203.49), and end-of-life leases (see 30 CFR 203.50 to 203.56). The BLM provides royalty relief only for a lease's end-of-life (equivalent to the BOEM's regulations at 30 CFR 203.50 through 203.56). After reviewing BOEM's authority, the BLM concluded that the BOEM's regulations were based on specific legal authorities that the BLM does not have. Therefore, the BLM is not proposing any changes to this section at this time. The existing regulations require evaluation of royalty reduction applications on a lease-by-lease basis, require applicants to provide a detailed statement with “all facts tending to show whether the wells can be successfully operated upon the fixed royalty or rental,” and generally provide for royalty rate reductions. The BLM is committed to adhering to those rules and will ensure that they are consistently and faithfully applied to future royalty relief applications.

The BLM solicits feedback to improve the royalty rate reduction section. Revised regulations could provide explicit criteria on royalty rate reductions, which could include setting a limit on the lower end of a royalty rate reduction, implementing a calculation to decide if the BLM should approve a royalty rate reduction, implementing an automatic lifting provision similar to BOEM (see 30 CFR 203.55), or making it explicit that a royalty rate reduction would transfer to the new lessee when a lease is assigned.

Sections 3103.4–2 Stripper Well Royalty Reductions and 3103.4–3 Heavy Oil Royalty Reductions

The proposed rule would eliminate both of these sections in their entirety because they are obsolete. Both sections were revised on October 6, 2010 (75 FR 61624), to eliminate these types of royalty relief. However, these provisions were retained in the final rule because, while these types of royalty relief were no longer available for current production, prior production subject to this relief continued to be subject to audits. In addition, the 7-year statute of limitations period during which ONRR could pursue a demand for royalty continued to apply. Since that statute of limitations period has passed for all production that qualified for relief under these sections, they are no longer necessary and are being removed.

Section 3103.42 Suspension of Operations and/or Production

This section of the existing regulations implements the provisions of 30 U.S.C. 226(i) and 209 for suspending oil and gas leases. The proposed rule would redesignate this section from 43 CFR 3103.4–4 to 43 CFR 3103.42 as discussed at the beginning of the preamble. The proposed rule would change the language in paragraph (b) to clarify that the term of a suspended lease will be adjusted to account for the time of suspension, i.e., by calculating the running of the primary term without including the time during which the lease was suspended. In the BLM's experience, the language in the current regulations—providing that the primary term of a lease will be “extended by adding the period of the suspension”—has been incorrectly interpreted to mean that the length of the suspension is added to the lease term when the suspension is lifted. For example, consider a lease issued for a primary term of 10 years. In the ninth year, a suspension is granted. The suspension lasts for 2 years. When the suspension is lifted, the time remaining on the primary term is the 1 year that was left prior to the suspension. The 2 years of the suspension are not added to the primary term.

Paragraph (d) would be clarified to state that if there is any production sold or removed during the month the suspension is granted, the lessee must pay royalty on that production. Paragraph (d) would also be split into three sections due to the length of the paragraph and for clarity. The other two sections would become new paragraphs (e) and (f), and the remaining paragraphs would be redesignated.

Redesignated paragraph (g) would update the term “terminating a suspension” to “lifting a suspension,” since “termination” is a term of art that refers to a lease ending through operation of law when the rental is not paid.

The proposed rule would update redesignated paragraph (h) to change the language from “unit or cooperative plan” to read “agreement” to conform to the definitional change made earlier in this proposed rule.

6. Section-by-Section Discussion for Changes to 43 CFR Subpart 3104

The BLM proposes to revise its oil and gas bonding requirements in several respects. The BLM proposes to increase minimum bond amounts for the first time since 1951 (statewide and nationwide bonds) and 1960 (lease bonds). In addition, the proposed rule would add one section, § 3104.90, into the existing subpart 3104 regulations to address when lessees must come into compliance with the new bond amounts and would revise two section headings in the existing subpart 3104 to more accurately reflect the contents of those sections. The proposed rule would also remove nationwide and unit operator's bonds and add surface owner protection bonds. The BLM believes these proposed changes, particularly the increased bond amounts and the elimination of nationwide bonding, would help ensure that reclamation responsibilities reside primarily with oil and gas lessees and operators and not the American public.

The MLA authorizes the Secretary to establish standards “as may be necessary to ensure that an adequate bond, surety, or other financial arrangement will be established prior to the commencement of surface-disturbing activities on any lease, to ensure the complete and timely reclamation of the lease tract, and the restoration of any lands or surface waters adversely affected by lease operations after the abandonment or cessation of oil and gas operations on the lease.” (30 U.S.C. 226(g)). The existing regulations at § 3104.1 implement this authority and require that, prior to surface-disturbing activities related to drilling operations, the lessee, sublessee, or operator submit a surety or personal bond. The purpose of the bond is to ensure the “complete and timely plugging of the well(s), reclamation of the lease area(s), and the restoration of any lands or surface waters adversely affected by lease operations after the abandonment or cessation of oil and gas operations.” (43 CFR 3104.1(a)). The regulations at §§ 3104.2 through 3104.4 currently set forth four different bond types:

○ Lease/Individual Bonds, which provide coverage for one lease and must be in an amount of not less than $10,000;

○ Statewide Bonds, which cover all leases and operations in one State and must be in an amount of not less than $25,000;

○ Nationwide Bonds, which cover all leases and operations nationwide and must be in an amount of not less than $150,000; and

○ Unit Operator's Bonds, which may be used in lieu of individual lease, statewide, or nationwide bonds for operations conducted on leases committed to an approved unit agreement.

Existing regulations set a minimum amount for these types of bonds. The BLM has not increased its minimum bond amounts since 1951 (statewide and nationwide bonds) and 1960 (individual lease bonds). In September of 2019, the GAO issued a report recommending that the BLM address risks from insufficient bonding (GAO–19–615). The GAO found the bonds held by the BLM were insufficient to prevent wells from becoming orphan wells and thereby shifting the costs to plug and abandon and reclaim these wells onto the taxpayer. Specifically, GAO found that 84 percent of the bonds reviewed were not sufficient to cover the costs to reclaim the wells covered by the bonds. Further, GAO determined the bond amounts, which were usually set at the regulatory minimum, “does not account for variables such as the number of wells [the bonds] cover or other characteristics that affect reclamation costs, such as well depth.”

Currently, the BLM uses Instruction Memorandum 2019–014, Oil and Gas Bond Adequacy Reviews, to review existing Federal bond amounts and request increases to the bond amount based on the potential risk or liability posed by the operators. Similar policy has been in place for the past decade, see Instruction Memorandums 2013–151, 2010–161, 2008–122, and 2006–206. The BLM is proposing to increase the minimum bond amounts to reflect inflation and the minimum coverage that would be required for operations on Federal land, based on the BLM's estimate of current plugging and reclamation costs. The proposed minimum bond amounts would provide sufficient protection to allow an operator to begin drilling; however, the BLM would still need to review bond amounts periodically to determine whether the bond amount should be increased based upon the risk of default posed by the operator or the risk to the environment posed by the operations. In the past 2 fiscal years, the BLM has spent $2.7 million annually on orphaned wells. Without an increase in the bond amounts, the BLM expects to continue to incur similar annual costs to address orphaned wells. Because of inflation, the lack of increased bond amounts for almost 40 years, and the increased number of orphaned wells resulting from insufficient funds available under current bonds and associated costs ultimately borne by the American taxpayer, the revisions to the bond amounts proposed here are justified.

In addition to the proposed rule, the BLM also considered two alternatives: adjusting the bond only for inflation (alternative 2) and requiring a full liability bond (alternative 3). The second alternative, only adjusting the bond amount for inflation, would increase the lease/individual bond to $100,000 and the statewide bond to $300,000. The third alternative considered adjusting the bond to cover the full plugging and reclamation cost of all Federal onshore operations covered by the bond. In this alternative, the BLM would allow the operator to use either a statewide bond or an individual bond; however, the operator would be required to submit a bond rider for each additional well drilled to ensure the bond amount covers the full cost for plugging and reclamation for all wells covered by the bond. In this instance, the BLM estimated an average lease/individual bond of $994,000 would cover 14 wells and an average statewide bond of $4,686,000 would cover 66 wells. The BLM concluded that implementing the third alternative would require increased staffing at the field and state offices to manage increased workload surrounding the additional bond riders. In addition, it is expected that the BLM's application for permit to drill processing time would slow down due to waiting for additional bond riders.

Although the BLM analyzed the second and third alternatives in the economic analysis, the BLM did not propose either of these alternatives in the proposed rule. The BLM is requesting commenters to provide information on additional alternatives for bonding that the BLM might consider.

Additionally, the BLM is requesting comments on whether it should propose to adjust the minimum bond amounts by inflation. Currently, the BLM is not proposing this in the rule; however, the BLM would prefer to have a method to adjust minimum bond amounts by inflation factors. Please provide comments on if and how the BLM should adjust minimum bond amounts in the future.

Finally, the BLM also proposes to remove the nationwide and unit operator bond types to reduce the cost and burden on the American public for administering these types of bonds. For nationwide bonds, the state office that is administering a nationwide bond must coordinate with not only the field offices within the state, but also every other state office. With the proposed elimination of nationwide bonds, the BLM would not need to coordinate with all the other state offices for a bond adequacy review. In addition, the BLM state office could more easily ensure that the field offices within the State have completed the required bond reviews. As a result, the BLM would be able to better tailor the bond amounts to the local conditions and State-specific requirements when reviewing a bond for adequacy. The BLM also would be able to review statewide bond amounts and ensure that the bond amount is adjusted before an operator defaults, thus reducing the financial burden on the American taxpayer. Overall, the elimination of nationwide bonding in favor of the proposed increase in the amount of the statewide and lease bonds would allow the agency to ensure improved bonding, with an appropriate focus on specific areas and fields, which should reduce the burden to the taxpayer if an operator fails to complete proper plugging and abandonment.

Section 3104.10 Bond Obligations

To enhance the administration of oil and gas bonding on America's public lands, the BLM is proposing to remove paragraphs (c)(1) and (5), which allow certificates of deposits (CDs) and letters of credit (LOCs) to secure a personal bond. The BLM is proposing to remove CDs because they are difficult to manage: the face of these instruments do not include the BLM's required language that Secretarial approval is required prior to redemption of the CD by any party. The BLM is proposing to remove LOCs because the BLM has found it is difficult for banks to include the BLM's requirements in LOCs. Under the proposed rule, any existing personal bond that is secured by a CD or a LOC need not change the security until the bond is replaced. However, the BLM would not accept CDs or LOCs as security for a new personal bond after the final rule takes effect. Finally, the BLM requests comments with any supporting information on whether the final regulation should provide for any other types of approved financial arrangements and the types of financial arrangements that the BLM should consider.

Section 3104.20 Lease Bond

The proposed rule would change the specifications regarding who must post a bond to state that the operator must be covered by a bond in its name as principal or obligor. The existing regulations authorize a lessee, owner of operating rights (sublease), or operator to post a lease bond. The proposed change would not result in any administrative changes for the BLM, because under the existing regulations, when a lessee or an operating rights owner posts the bond for the operator, the bond must include the operator as principal. The proposed language is intended to simplify these provisions by requiring an operator to have a bond in its own name and removing the requirement for lessees and sublessees to ensure their bonds cover the operator. The BLM recognizes that lessees and owners of operating rights (sublessees) have certain obligations and are ultimately responsible for operations on their lease, as required by 43 CFR 3106.76, and additional bonding may be required by the authorized officer when, for example, an operator is noncompliant.

The proposed rule would increase the minimum lease bond amount to be not less than $150,000. The existing lease bond amount of $10,000, established in 1960, no longer provides an adequate incentive for companies to meet their reclamation obligations, nor does it cover the potential costs to reclaim a well should this obligation not be met. This current bond requirement increases the risk that taxpayers will cover the cost of reclaiming wells in the event the operator refuses to do so or declares bankruptcy. According to a GAO report entitled, Federal Energy Development, Challenges to Ensuring a Fair Return for Federal Energy Resources, GAO–19–718T, “weaknesses with bonds for coal mining and for oil and gas development pose a financial risk to the Federal Government as laws, regulations, or agency practices have not been adjusted to reflect current economic circumstances.”

To determine the appropriate minimum lease bond amount, the BLM reviewed its existing lease bonds and the number of wells tied to the lease bonds. The BLM currently manages 933 lease bonds; however, only 369 lease bonds cover existing wells or liability. The lease bonds that do not cover any existing liability are usually put in place for a well that has not yet been drilled or where the principal forgot to request termination of the bond after transferring or plugging and abandoning its prior oil and gas liability. For the lease bonds with existing wells, each lease bond, on average, covers 14 wells; however, lease bonds cover a median number of one well per bond. In addition, the lease bonds covering existing wells average $26,000 per bond. For background, the BLM calculated the average by adding up all the lease bond amounts and dividing this total by the number of lease bonds. The BLM calculated the median by taking the middle value, i.e., the value for which half of the lease bonds are larger and half are smaller. Thus, half of the lease bonds with existing liability cover one well per bond. The cost to plug one well and reclaim the surface, however, can vary significantly based on the depth of the well. The proposed rule would require the minimum bond amount to be sufficient to reclaim two wells to account for the uncertainty surrounding the depth of wells and the large variability in reclamation costs for orphaned wells. The BLM would conduct bond adequacy reviews on all bonds and increase the required bond amount based upon the risk of the operations. This review would include several risk factors regarding the wells covered by the bond and the operator's compliance history.

Between 1960 and 2022, the cumulative inflation rate, as measured by the U.S. Consumer Price Index was 901 percent and, accordingly, the 2022 equivalent of $10,000 (the 1960 lease bond amount) would be $100,105 ( https://www.usinflationcalculator.com ). After reviewing the costs to plug orphaned wells, the BLM determined the cost to plug a well and reclaim the surface ranges from $35,000 to $200,000, with an average cost of $71,000. Considering that the median number of wells is one well per lease bonds, the BLM is proposing to set the new minimum lease bond amount at $150,000 (rounded up from $142,000), which would cover the estimated plugging and reclamation costs for two wells. The BLM is proposing to round the bond amount up to the nearest $50,000 for ease of payment and administration. Through the BLM's current policy for bond adequacy reviews, the BLM will increase the lease bond amount for operators with more than two wells tied to the bond. The proposed minimum lease bond amount would provide sufficient coverage for an operator starting operations with a lease bond.

Based upon a review of the lease bond and related operations, the BLM determined that the minimum lease bond amount should be not less than $150,000. In addition, the minimum lease bond amount of $150,000 matches the amounts proposed in Congress by Senator Michael Bennet (S. 2177) and Representative Teresa Leger Fernandez (H.R. 2415). The BLM believes this update would help ensure that reclamation responsibilities reside primarily with oil and gas lessees and operators and not the American public. The BLM requests comments with any supporting information on whether the final regulation should provide a higher or lower amount for lease bonds.

Section 3104.30 Statewide Bonds

The proposed rule would rename this section from “Statewide and nationwide bonds” to “Statewide Bonds” as BLM proposes to remove nationwide bonds. The proposed rule increases the statewide bond amount to not less than $500,000, covering all leases and operations in any one State to reflect current economic circumstances. The BLM established the previous statewide bond amount of $25,000 in 1951. As stated earlier, insufficient bonding levels provide an inadequate incentive for companies to meet their reclamation obligations and do not provide sufficient funding in the event a company fails or refuses to meet its obligations, thereby ultimately shifting the reclamation obligations on the taxpayer.

To determine the appropriate minimum statewide bond amount, the BLM reviewed its existing statewide bonds, and the number of wells tied to the statewide bonds. The BLM currently manages 1,815 statewide bonds; however, only 1,007 statewide bonds cover existing wells. For the statewide bonds with wells, each statewide bond, on average, covers 66 wells; however, the statewide bonds cover a median number of seven wells per bond. The larger number of wells covered provides the BLM more time to conduct a bond adequacy review and increase bond amounts if needed. In addition, the statewide bonds covering existing wells averaged $387,000 per bond. For background, the BLM calculated the average by adding up all the statewide bond amounts and dividing this total by the number of statewide bonds. The BLM calculated the median by taking the middle value, i.e., the value for which half of the statewide bonds are larger and half are smaller. Since half of the statewide bonds, with existing liability, cover seven wells per bond, the proposed rule would require the minimum bond amount to cover seven wells, the median number of wells. Unlike bonds for individual leases where the BLM is proposing to cover more than the median number of wells, for statewide bonds, the larger number of wells covered (7) reduces the uncertainty related to depth of individual wells and the variability of reclamation costs. It also gives the BLM more time to conduct a bond adequacy review and increase bond amounts if needed. The BLM would conduct bond adequacy reviews on all bonds and increase the required bond amount based upon the risk of the operations. This review would include the number of wells covered by the bond.

Between 1951 and 2022, the cumulative inflation rate, as measured by the U.S. Consumer Price Index was 1,040 percent and, accordingly, the 2022 equivalent of $25,000 (the 1951 statewide bond amount) would be $284,914 ( https://www.usinflationcalculator.com ). After researching the BLM's data on orphaned wells, the cost to plug a well and to reclaim the surface ranged from $35,000 to $200,000, with an average cost of $71,000. Considering that the median number of wells is seven wells per statewide bond, the BLM opted to have the minimum statewide bond cover seven wells, which resulted in a statewide bond of $500,000, rounded from $497,000. The BLM rounded the bond to the nearest $50,000 for ease of payment and administration. Through the BLM's current policy for bond adequacy reviews, the BLM will increase the statewide bond amount for operators with more than seven wells tied to the bond. The new minimum statewide bond amount would provide sufficient coverage for an operator starting operations with a statewide bond.

Based upon a review of the statewide bond and related operations, the BLM determined that the minimum statewide bond amount should be not less than $500,000. In addition, the minimum statewide bond amount of $500,000 matches the amounts proposed in congress by Senator Michael Bennet (S. 2177) and Representative Teresa Leger Fernandez (H.R. 2415). The BLM believes this update would help ensure that end-of-life liabilities reside primarily with oil and gas lessees and operators and not the American public. The BLM requests comments with any supporting information on whether the final regulation should provide a higher or lower amount for statewide bonds.

Finally, the proposed rule would rescind the use of nationwide bonds, which call upon the BLM to manage nationwide risks and liabilities and are therefore administratively inefficient. The elimination of nationwide bonding in favor of the proposed increase in the amount of the statewide and lease bonds described earlier would allow the agency to ensure improved bonding, with an appropriate focus on specific areas and fields, which should reduce the burden to the taxpayer if an operator fails to complete proper plugging and abandonment.

For more background, the BLM reviewed its existing nationwide bonds, and the number of wells tied to the nationwide bonds. The BLM currently manages 241 nationwide bonds; however, only 129 nationwide bonds cover existing wells or liability. For the nationwide bonds with wells, each nationwide bond, on average, covers 295 wells; however, the nationwide bonds cover a median number of 35 wells per bond. The nationwide bonds covering existing wells averaged $198,000 per bond. Compared to statewide bonds, nationwide bonds cover more wells and averaged lower amounts per bond. The BLM believes the increased administrative burden related to managing nationwide bonds has caused nationwide bonds to lag behind statewide bonds for bond increases and reviews. Overall, the BLM believes the elimination of nationwide bonds would result in prompt adjustments to bond amounts with changing circumstances of the bonded parties' operations. The BLM seeks public comment on the appropriate minimum amount for a nationwide bond, if it opts to retain the nationwide bonding provision.

Section 3104.4 Unit Operator's Bond

The proposed rule would eliminate unit operator bonds in their entirety, as currently found in 43 CFR 3104.4. Currently, these bonds are treated like statewide bonds and may be used in lieu of individual lease, statewide, or nationwide bonds for operations conducted on leases committed to an approved unit agreement. The language for the unit operator bond can be found at 43 CFR 3186.2. The BLM has less than 20 active unit operator's bonds nationwide. The BLM's review of bonds shows that the forms predating June 1987 did not clearly cover the principal in the capacity of a unit operator where the operator does not hold an interest in the lease. Prior to June 1987, the BLM required the principal or obligor to provide a rider to a statewide or nationwide bond extending the bond's coverage to include all obligations of the principal or obligor under the terms and conditions of unit agreements. The current bond forms do not have this deficiency as they contain the statement, “WHEREAS the principal and surety agree(s) that with notice to the surety the coverage of this bond, in addition to the present holding(s) of and/or authorization(s) granted to the principal, shall extend to and include: [. . .] Any activity subsequent hereto of the principal as operator under a lease(s) issued pursuant to the Acts cited in this bond.” Today, unit operator bonds are usually submitted to the BLM when a unit agreement includes lands located in more than one State as it costs less to post a single unit operator bond for $25,000 rather than posting two statewide bonds for $50,000 or a nationwide bond for $150,000. This was not BLM's intention for the unit operator bond in 1987 when the bond forms were updated. Therefore, eliminating and replacing the unit operator's bond, which is already treated and managed like statewide bonds, would bring efficiencies to the program.

Section 3104.40 Surface Owner Protection Bond

The proposed rule would add a provision related to surface owner protection bonds to consolidate all of the bonding provisions in one place. The BLM promulgated the current requirements for surface owner protection bonds through Onshore Order 1 in 2007. The BLM recently codified these requirements in 43 CFR subpart 3171. In this proposed rule, the BLM would incorporate the existing bonding requirements set out in Onshore Order 1. It also would add a new requirement that the surface owner protection bond must be filed on the BLM approved form and specify that the type of bond can either be a personal or surety bond. The BLM requests supporting documentation and comments on whether the final rule should change the minimum bond amount for surface owner protection bonds.

Section 3104.60 Where Filed and Number of Copies

The proposed rule would remove the last sentence in this paragraph, which states that nationwide bonds may be filed in any BLM state office. As noted previously, this rule would eliminate nationwide bonds.

Section 3104.70 Default

The proposed rule would divide the current paragraph (b) into three paragraphs for clarity. Paragraph (b)(1) would state that all the leases covered by the bond may be subject to cancellation if the principal fails to comply with the paragraph (b) requirements. The BLM proposes to add information on failure to comply by referencing section 17 of the MLA and the DOI's suspension and debarment program to ensure the bonded principal understands the risks that incur for a default under the bond. The rule proposes to add paragraphs (b)(2) and (3). Paragraph (b)(2) would state that the bonded party may be prevented from acquiring any new lease or interest when the entity is in violation of section 17 of the MLA; it references the provisions for qualifications to hold a lease at 43 CFR 3102.51(f). Paragraph (b)(3) would state that the bonded party may be referred to the DOI's Suspension and Debarment Program under 2 CFR part 1400 to determine if the person will be suspended or debarred from doing business with the Federal Government for failure to comply with the paragraph (b) requirements.

Section 3104.90 Bonds Held Prior to [EFFECTIVE DATE OF THE FINAL RULE]

The proposed rule would add a new section entitled “Bonds Held Prior to [EFFECTIVE DATE OF THE FINAL RULE]” to manage the elimination of existing nationwide and unit bonds. Paragraph (a) would state that the current unit operator bonds accepted by the BLM prior to the effective date of the final rule must be replaced by a statewide bond within 2 years from the effective date of the final rule. The BLM would no longer accept new unit operator bonds. Paragraph (b) would provide a phase-in period within which bonds held prior to the final rule must meet the increased minimum bond amounts. The phase-in period for individual, state, and nationwide bonds would be 1, 2, and 3 years, respectively (for nationwide bonds, the phase-in period refers to the time in which nationwide bonds must be converted into state bonds).

The phase-in period should be as short as possible to account for the large number of inadequate bonds and the associated taxpayer exposure. The BLM opted for a 3-year phased approach based on the workload related to reviewing and accepting new bonds or bond riders. This approach would spread out the workload of replacing bonds over a 3-year period and allow the BLM to process the bond increases without requiring additional adjudication staff to manage the increased workload. The BLM opted to start with individual bonds as these are usually smaller operations with an increased risk of bankruptcies. The BLM requests supporting documentation and comments on whether the final regulation should change the priority order for the phase-in period.

7. Section-by-Section Discussion for Changes to 43 CFR Subpart 3105

The proposed rule would add one section and remove five sections in existing 43 CFR subpart 3105. The proposed rule would revise one section heading in the existing 43 CFR subpart 3105 to remove an unnecessary reference to drilling agreements.

Section 3105.10 Cooperative or Unit Agreement

The proposed rule would add a new paragraph (b) to this section to require that all applications to form a unit agreement, a unit expansion, or a designation of a successor operator include the new processing fee found in the fee schedule in 43 CFR 3000.120 of this chapter.

Communitization Agreements

This section of the regulations covers the BLM's management and approval of communitization agreements, which are oil and gas agreements covering one or more Federal leases that cannot be independently developed due to well-spacing or well development programs. The CA allows the lessees to cooperatively develop such tracts. The proposed rule would rename this section from “Communitization or Drilling Agreements” to “Communitization Agreements.” The proposed rule would eliminate “drilling agreements” in this section, since the BLM has determined that such agreements are rarely if ever used.

Section 3105.21 Where Filed

The proposed rule would remove the triplicate filing requirement in paragraph (a) as the BLM believes this requirement is no longer needed given electronic filing. The proposed rule would replace the language in current paragraph (b) with a list of three items that an application for a CA must include. Paragraph (b)(1) would require that all applications to form a CA must include a statement as to whether the proposed CA deviates from the BLM's current model CA form and a certification that the applicant received the required signatures. Paragraph (b)(2) would require an Exhibit A to display a map of the area covered by the agreement and the separate agreement tracts, and paragraph (b)(3) would require the filing of an Exhibit B displaying the separate tracts and ownership. The new paragraph (c) would state that all applications to form a CA should be submitted at least 90 calendar days prior to first production to ensure accurate reporting to the ONRR. Finally, the new paragraph (d) would require operators to file the designation of successor operator with the filing fee in the fee schedule at 43 CFR 3000.120.

Section 3105.22 Purpose

The proposed rule would remove the unnecessary reference to drilling agreements.

Section 3105.23 Requirements

The proposed rule would remove the unnecessary reference to drilling agreements.

Section 3105.24 Communitization Agreement Terms

The proposed rule would add a new section to outline CA terms to provide clarity. The new paragraph in this section would provide that these agreements would remain in effect for a period of 2 years from the effective date of the CA or approval date, whichever is later, and as long thereafter as communitized substances may be produced in paying quantities, or as otherwise specified in the agreement.

Section 3105.31 Where Filed

The proposed rule would remove the requirement for five copies of an operating, drilling, or development contract to be submitted when these contracts are submitted to the BLM for approval as the BLM believes this requirement is no longer necessary because of electronic filing.

Section 3105.4 Combination for Joint Operations or for Transportation of Oil

The proposed rule would eliminate the section on the combination for joint operations or for transportation of oil. These provisions are not used by the BLM or operators and are therefore obsolete. A ROW for pipelines may be granted, as provided in 43 CFR part 2880, without retaining the duplicative language under this subpart. A ROW grant is an authorization to use a specific piece of public land for a certain project, such as a road, pipeline, transmission line, or communication site. A more complete explanation of the BLM ROW program is found in Title 43 CFR parts 2800 and 2880.

Subsurface Storage of Oil and Gas

The proposed rule would change the existing 43 CFR 3105.5 to just the heading “Subsurface storage of oil and gas.”

Section 3105.41 Where Filed

The proposed rule would update paragraph (a) to include designation of successor operators for gas storage agreements among the applications to be filed in the proper BLM office. This information needs to be filed with the BLM when there is a change in operator. The proposed rule would update paragraph (b) to remove the requirement for five copies of a gas storage agreements to be submitted when these are filed with the BLM as the BLM believes this requirement is no longer necessary because of electronic filing. A new paragraph (c) would require that all applications for a subsurface gas storage agreement or a designation of a successor operator must include the new processing fee found in the fee schedule in 43 CFR 3000.120.

Section 3105.42 Purpose

The proposed rule would add clarification that a gas storage agreement will require a bond under 43 CFR part 3104.

Section 3105.43 Requirements

The proposed rule would update the language in this section to mirror the language found in 43 CFR 3105.42 for clarity.

Section 3105.50 Consolidation of Leases

The proposed rule would split the single paragraph under this section into several paragraphs for clarity. These paragraphs would also incorporate language from 43 CFR 3135.17 to provide a consistent approach across leasing in the NPR–A and under the MLA. Paragraph (a) would incorporate language stating that leases may be consolidated upon written request of the lessee filed with the proper BLM office. This change is proposed to identify who should submit the request for consolidation. The request must identify each lease involved by serial number and must explain the factors that justify the consolidation. Paragraph (b) would state that all parties holding any undivided interest in any lease involved in the consolidation must agree to enter into the same lease consolidation. Consistent with the existing language, paragraph (c) would clarify the circumstances under which leases cannot be consolidated. Paragraph (d) would state that a consolidated lease will not exceed acreage limits of 2,560 acres for competitive leases and 10,240 acres for noncompetitive leases, as required by 30 U.S.C. 226. Paragraph (e) would require the effective date, anniversary date, and the primary term of the consolidated lease to be those of the oldest original lease included in the consolidation. It would also allow the term of a consolidated lease to be extended beyond the primary lease term pursuant to 43 CFR subpart 3107. Paragraph (f) would state that the highest royalty and rental rates of the each of the leases to be consolidated would apply to the consolidated lease. Paragraph (g) would state that lease stipulations and other terms and conditions of each original lease would, in general, continue to apply to the lease to which they originally applied, regardless of the lease becoming a part of a consolidated lease. These additions bring consistency between §§ 3135.17 and 3105.50.

8. Section-by-Section Discussion for Changes to 43 CFR Subpart 3106

The proposed rule would add one section and remove two sections in existing subpart 3106. The proposed rule would revise five section headings in the existing subpart 3106 to provide clarity and replace the existing question-and-answer formats.

Section 3106.10 Transfers, General

The proposed rule would split paragraph (a) into two paragraphs and add a provision regarding transfers of operating rights to provide clarity and reduce the confusion the BLM has seen in applications. The new paragraph (b) would state that an assignment of a separate zone, deposit, depth, formation, a specific well, or part of a legal subdivision will be denied. The proposed rule would add a new paragraph (c) to state that operating rights may only be divided with respect to legal subdivisions, depth ranges, and formations within the boundaries of a Federal lease. Terms, such as stratigraphic equivalent, pools, reservoirs, wellbores, and references to unnamed formations occurring at a specified depth within a specific well are not allowed, as they are not definitive, and introduce ambiguity into the boundaries along which lease rights are split.

The proposed language more clearly states the BLM's current obligations. The current regulation at 43 CFR 3106.1(a) states: “Leases may be transferred by assignment or sublease as to all or part of the acreage in the lease or as to either a divided or undivided interest therein. An assignment of a separate zone or deposit, or of part of a legal subdivision, shall be disapproved.” The “stratigraphic equivalent” of a formation ( i.e., a division that extends beyond that formation) meets the definition of a “zone.” A “pool” of oil or gas trapped in the rocks below the ground surface meets the definition of a “deposit.” Under the current regulations, therefore, the BLM must disapprove these types of assignments.

The BLM's practice is sound as a practical matter. The BLM cannot approve assignments or transfers that attempt to separate rights along boundaries that cannot be defined without geological interpretation (for example, “the stratigraphic equivalent of the formation encountered in Well X, at a depth of Y feet below the surface”). A boundary that requires geological interpretation is inherently imprecise. As for wellbore-only transfers, a wellbore is essentially a line, not a spatial region within a leasehold. The BLM cannot define a distribution of lease rights relative to a linear feature in three-dimensional space below the surface of the ground. Wellbore-only rights that purportedly encompass the area drained by that wellbore pose the problem of defining the boundaries of the area drained, which may require geological interpretation and/or engineering analysis.

The proposed rule would also split the existing paragraph (b) into five paragraphs due to the length of the paragraph and for clarity. The proposed paragraph (d) would revise the second sentence to simply reference 43 CFR 3102.51(g) for certification of compliance rather than repeating the language set out in 43 CFR 3102.51(g). The proposed rule would redesignate the existing paragraph (c) to paragraph (i) because of the previously mentioned reorganization.

Section 3106.20 Qualifications of Transfers

The purpose of this section is to ensure new lessees and operating rights owners comply with the provisions of 43 CFR subpart 3102. The proposed rule would update the title of the section from “Qualifications of transferees” to “Qualifications of assignees and transferees.” The proposed rule would also update the paragraph to include “assignees” as well as “transferees.” The purpose of these changes is to clarify that this section on qualifications applies to both assignments of record title as well as transfers of operating rights. The proposed rule would add a sentence that states “Only qualified and responsible lessees may own, hold, or control an interest in a lease.” This addition is made to conform the language in this provision with similar proposed changes.

Section 3106.30 Fees

This section includes the requirement to submit the requisite filing fees with assignment and transfer applications. The proposed rule would split the current paragraph into two paragraphs for clarity. The reference to the filing fee for assignments and transfers would now be found under paragraph (a). The reference to the filing fee for transfer of overriding royalty or payment out of production would now be found under paragraph (b). References to the filing fees for mergers and name changes and for transfers to heirs or devisees would be removed from this section as the filing fee requirement is included in the sections for those specific topics.

Section 3106.41 Transfers of Record Title and of Operating Rights (Subleases)

This section describes the forms required for assignment and transfers. The proposed rule would update this section to allow for the acceptance of electronic submissions. The proposed rule would reduce the triplicate filing to a duplicate filing so that the BLM can keep one copy for the official case file and return one copy of the approved assignment or transfer for the applicant's records. The BLM does not require a duplicate copy of the assignment or transfer when it is electronically submitted.

The proposed rule would also require assignments and transfers to be submitted on a current form and would no longer allow the use of obsolete forms. All current forms can be located on the BLM's web pages. The BLM believes that lessees may locate the current form far easier now than in the days prior to widespread internet access.

The current regulations allow for the assignee or transferee to sign only one copy of the assignment or transfer, while the assignor or transferor must sign all three copies of the form. In light of the proposal to reduce the triplicate filing to (at most) a duplicate filing, the BLM believes it would no longer be a burden for the assignee or transferee to sign both copies of the form submitted to the BLM. This change would streamline the BLM's verification of the required signatures.

Section 3106.42 Transfers of Other Interest, Including Royalty Interests and Production Payments

The proposed rule would update paragraphs (a) and (b) to ensure overriding royalty transfers are submitted on the BLM's current assignment or transfer forms.

Section 3106.43 Mass Transfers

This section allows an assignor or transferor to make a mass assignment or transfer when conveying any type of interest in a large number of Federal leases to the same assignee or transferee. The proposed rule would update paragraph (a) to include the words “assignor” and “assignee.” As explained earlier, the term “transferees” usually refers to transfers of operating rights, but this section has always functioned to apply to both assignments of record title as well as transfers of operating rights. The BLM believes that adding assignors and assignees to this language would reduce any confusion on this matter. In addition, the regulatory language was clarified to ensure that the minimum number of leases for a mass transfer is more than one lease.

The proposed rule would update paragraph (b) to reduce the triplicate filing to a duplicate filing so the BLM can keep one copy for the official case file and return one copy of the approved assignment or transfer for the applicant's records. The proposed rule would update paragraph (c) to state that the BLM does not require a duplicate copy of the assignment or transfer when it is electronically submitted. In addition, a new paragraph (c)(2) would be added to state that when the BLM does not receive the requisite number of copies for mass transfers, the applicant would reimburse the BLM for the full costs incurred to make the required number of copies. The BLM would waive any copy fees under one dollar.

Section 3106.50 Description of Lands

The proposed rule would update the language in this paragraph from “transfer of record title” to “assignment of record title” for consistency. In addition, the reference to 43 CFR 3110.5 would be removed to more simply state that each assignment must describe the lands in the same manner as the lands described in the lease.

Section 3106.60 Bond Requirements

The purpose of this section is to ensure the new lessee or operating rights owner obtains a bond equivalent in coverage to the assignor's or transferor's bond before approval of the assignment or transfer. The proposed rule would update the title of this section from “Bonds” to “Bond requirements.” This section would also consolidate the separate sections for “Lease bond” (43 CFR 3106.6–1) and “Statewide/nationwide bond” (43 CFR 3106.6–2) into one paragraph to streamline the regulations. In addition, the rule would remove references to a transferee or a new operator as a co-principal on the transferor's or operator's bond. In the BLM's experience, this dynamic does not occur. An assignee assumes all the obligations incurred by the assignor as well as the benefits that have accrued to the assignor. The bond the assignee, transferee, or new operator must provide is a proper bond that would cover any obligations arising under the lease to the same extent as the assignor's bond. The BLM's practice is to ascertain the adequacy of such bond before approving the assignment.

Approval of Transfer or Assignment

The proposed rule would change the existing 43 CFR 3106.7 “Approval of transfer” to the heading “Approval of transfer or assignment.” The reference to both assignments and transfers conforms the title of this section with similar proposed changes.

Section 3106.71 Failure To Qualify

The proposed rule would update the paragraph in this section to active voice and update the language from “transfer of record title or of operating rights (sublease)” to “assignment of record title or transfer of operating rights (sublease),” consistent with the other changes made to this subpart. In addition, the term “qualified lessee” is used in place of the existing language “qualified to hold the transferred interest.” i.

Section 3106.72 Continuing Obligation of an Assignor or Transferor

The purpose of this section is to describe the continuing obligation of the assignor or transferor after the BLM approves the assignment or transfer. The proposed rule would update the title and paragraphs of this section to remove the question-and-answer format. The title would change from “If I transfer my lease, what is my continuing obligation?” to read “Continuing obligation of an assignor or transferor.” In paragraph (a), the proposed rule would change “you are responsible” to “the lessee or sublessee remains responsible” and paragraph (b) would change “you” to “the assignor or transferor.” This is intended to clarify who “you” is in this section.

Section 3106.73 Lease Account Status

The proposed rule would update this section to active voice and revise the phrase “unless the lease account is in good standing” to clarify that the lease account must not be delinquent with respect to royalty payments; lease obligations, such as, but not limited to, rent and minimum royalty; or production reporting to the ONRR for a lease in non-terminable status.

Section 3106.75 Effect of Transfer

This section requires that an assignment to 100 percent of a portion of the lease segregates the transferred and retained portions into separate leases. The proposed rule would update the language in this paragraph from “transfer of record title” to “assignment of record title,” consistent with the other changes made to this subpart. The proposed rule would also update the paragraph in this section to clarify the meaning of undivided interest to the more commonly used phrase of “less than 100 percent of a portion of the lease.”

Section 3106.76 Obligations of Assignee or Transferee

The purpose of this section is to describe the obligations the lessee or sublessee assumes after the BLM approves the assignment or transfer. By seeking approval of the assignment or transfer and being substituted in place of the assignor or transferor, the assignee or transferee assumes the responsibility for complying with all lease obligations in existence and that a purchaser exercising reasonable diligence should have known existed at the time of the transfer. The proposed rule would update the title and paragraphs of this section to remove the question-and-answer format. The title would change from “If I acquire a lease by an assignment or transfer, what obligations do I agree to assume?” to read “Obligations of assignee or transferee.” This formatting change brings overall consistency with the other regulations in this subpart. The proposed rule would also replace “you” in this section with “the record title holder” or “transferee of operating rights,” as appropriate. It would also state more clearly that the transferee assumes the responsibility to plug and abandon all wells that are no longer capable of producing.

Section 3106.81 Heirs and Devisees

The proposed rule would split paragraph (a) into two paragraphs for clarity. The existing paragraph (b) would become paragraph (c) due to the reorganization of the section. The language in paragraph (a) would be updated to state that the lease interest would be assigned or transferred to the heirs, devisees, executor, or administrator of the estate, as appropriate, upon the filing of a court order, death certificate, or other legal document demonstrating that the assignee is to be recognized as the successor of the deceased. New paragraph (b) would contain the requirement for the filing fee. Newly redesignated paragraph (c) would include a requirement to file a qualification statement, as well as the current language found in existing paragraph (b). The proposed rule would add a new paragraph (d) that would contain the bonding requirements that are found in paragraph (a) in the current regulation.

Section 3106.82 Change of Name

The proposed rule would split the reference to the filing fee and bond into three separate paragraphs for clarity. The current regulation requires a notice of the name change to be accompanied by a list of the serial numbers of the leases affected by the name change. This requirement would be removed, as it is outdated. In practice, the BLM generates a report of the leases affected by the name change and returns that list to the lessee with a notice that recognizes the name change. The proposed paragraph (a) would be updated to require that for a corporate name change, the request must include the Secretary of State's Certificate of Name Change, along with the Articles of Incorporation, or Amendment, if available. This is consistent with the BLM's current approach for processing these types of documents. New paragraph (b) would contain the requirement for the filing fee. The proposed rule would add a new paragraph (c) that would contain the bonding requirements that are found in the current regulation.

Section 3106.83 Corporate Mergers and Dissolution of Corporations, Partnerships, and Trust

The proposed rule would update the title of this section from “Corporate merger” to “Corporate Mergers and Dissolution of Corporations, Partnerships, and Trust.” The goal of renaming the section is to incorporate other types of changes to lease ownership interests that may occur without any intention by the holder of an interest to assign or transfer the interest. The proposed rule would split the current paragraph into three paragraphs for clarity.

The current regulation requires a notification of merger to be accompanied by a list of the serial numbers of the leases affected by the merger. This requirement would be removed, as it is outdated. In practice, the BLM does not rely on a list of leases provided by a lessee and, instead, generates its own report of the leases affected by the merger. The BLM returns that list to the lessee with a notice that recognizes the corporate merger.

This section would be updated to require that, for a merger, the request must include the Secretary of State's Certificate of Merger, along with the Articles of Incorporation, or Amendment, if available. This requirement is consistent with the BLM's current approach for processing these types of documents. New paragraphs would be added allowing the BLM to recognize lease interests assigned through dissolutions of corporations and dissolutions of partnerships and trust. The new provision would state that the BLM would not recognize any transfers provided by the Articles of Dissolution unless an entity has filed with the BLM a Certificate of Dissolution of an incorporated entity, certified as accepted by the State where the entity was incorporated. Dissolution of a partnership or trust through an order or decree that authorizes settlement, discharge, and distribution of the lease holdings and/or interests must be filed with the BLM for official recognition of the assignment of lease interests. These requirements are consistent with the BLM's current approach for processing these types of documents.

Section 3106.84 Sheriff's Sale/Deed

The proposed rule would add a new section under § 3106.80, to include sheriff's sales as another type of transfer. The BLM accepts these types of assignments to recognize lease interests assigned to other parties through foreclosure actions. The proposed rule would state that where a notice of sale of the leasehold interest is published pursuant to State law applicable to the execution of sales of real property, the purchaser must submit to the proper BLM office a copy of the Sheriff's Certificate of Sale after any redemption period has passed. Additional paragraphs under this new section would include a filing fee requirement, a qualification statement, and bonding requirements. These requirements are consistent requirements with the BLM's current approach for processing these types of documents.

9. Section-by-Section Discussion for Changes to 43 CFR Subpart 3107

The proposed rule would remove six sections in existing 43 CFR subpart 3107. The proposed rule would change the title of this subpart from “Continuation, Extension or Renewal” to “Continuation and Extension” due to the removal of the sections on renewal of leases, as explained later. The proposed rule would revise two section headings in the existing 43 CFR subpart 3107. The goal of the revisions is to replace “plans” with “agreements” to provide clarity and to conform this language with other changes in this proposed rule.

Section 3107.10 Extension by Drilling

The proposed rule would split the existing paragraph into two separate paragraphs for clarity. In paragraph (a), a sentence would be added to state that the BLM would not grant a drilling extension for a lease in its extended term. This change would clarify and complement the first sentence of this section, which states that a drilling extension would only be granted for a lease on which actual drilling operations are being diligently pursued at the end of the primary lease term or any lease that is committed to an approved oil and gas agreement. A new paragraph (c) would be added to address directional or horizontal wells on off-lease locations by stating that when a BLM-approved directional or horizontal well is drilled within the leased area from an off-lease location with the intent to produce from the leased area, the BLM would consider drilling to have commenced on the leased area when drilling is commenced at the off-lease location. This addition is consistent with the leasing regulations under 43 CFR part 3130.

Section 3107.22 Cessation of Production

The proposed rule would update this section because the IBLA has held that the current regulations—which provide that “[t]he 60-day period commences upon receipt of notification from the authorized officer”—directly conflicts with the statutory provision of section 17(i) of the MLA (30 U.S.C. 226(i)). Refer to Two Bay Petroleum, Inc, 166 IBLA 329 (2005), International Metals & Petroleum Corp, 158 IBLA 15 (2002), and Merit Productions, et al., 144 IBLA 156 (1998). In summary, these cases explain that through operation of law a lease in its extended term expires 60 days following cessation of production, not 60 days after the lessee receives the BLM notice.

The paragraph in the proposed rule would now read that a lease in its extended term because of production (and lacking a well capable of production in paying quantities) would not expire upon cessation of production, if, within 60 calendar days of cessation of production, reworking or drilling operations on the leasehold are commenced and are thereafter conducted with reasonable diligence during the period of nonproduction. The proposed rule would also add a sentence stating, “If these reworking or drilling operations fail to result in production in paying quantities, the lease will expire by operation of law, effective as of the date production ceased.”

Section 3107.23 Leases Capable of Production

The proposed rule would update the existing paragraph to specify 60 “calendar days” in order to be clearer.

Section 3107.30 Extension for Terms of Agreements

The proposed rule would update the title of this section from “Extension for terms of cooperative or unit plan” to “Extension for Terms of Agreements.” This conforms this language to other changes in this proposed rule.

Section 3107.31 Leases Committed to an Agreement

The proposed rule would update the title of this section from “Leases committed to plan” to “Leases committed to an agreement.” The proposed rule would also remove the reference to the existing 43 CFR 3107.3–3 (renewal leases) due to the changes made to that section, as further described later.

The proposed rule would add a new paragraph (b) because IBLA cases have held that a well that is capable of production in paying quantities on a lease basis and that is completed on a committed tract within a unit agreement will extend the term of all expiring Federal leases committed to the unit agreement for the term of the unit agreement and/or for so long as the well is capable of production in paying quantities. Refer to Yates Petroleum Corp. 67 IBLA 246 (1982).

Section 3107.32 Segregation of Leases Committed in Part

This section addresses any lease committed to a unit agreement that covers less than the entirety of the lands covered by the lease. In paragraph (a), a sentence would be added to state that, for unproven areas, segregation would occur only when the public interest requirement is satisfied pursuant to 43 CFR 3183.4(b). The sentence would also provide that, upon satisfaction of the public interest requirement, the BLM would deem the segregation to have been effective as of the date of commitment of the lands to the unit. Segregating a lease after the public interest requirement is met would create efficiencies in the program. If the public interest requirement is not met, the BLM would not be required to consolidate the improperly segregated leases, and the ONRR would not be required to consolidate improperly segregated lease accounts for payments.

The proposed rule would delete the portion of existing paragraph (b), which described how a lease segregation would be declared invalid if the public interest requirement was not met. This change is consistent with the changes made to paragraph (a).

The proposed rule would add a new paragraph (b)(2) to clarify that the base or segregated lease may be extended by production on the associated lease by stating that, if a partially committed lease is in an extended term because of production, the segregated, non-producing lease would continue in effect so long as the producing lease exists and rentals are paid, and so long thereafter as oil or gas is produced from the committed lease.

Section 3107.3–3 20-Year Lease or Any Renewal Thereof.

The proposed rule would eliminate this section because it is outdated. All 20-year leases, also known as renewal leases, have either expired or are held by production. Renewal leases are further described in detail under 43 CFR 3107.80.

Section 3107.51 Extension After Discovery on Other Segregated Portions

The proposed rule would update the language in this paragraph from “the date of first discovery of oil or gas in paying quantities” to read “the date a well capable of production in paying quantities is established.” The change reflects language more commonly used by the BLM.

Section 3107.7 Exchange Leases: 20-Year Term

The proposed rule would eliminate this section because it is obsolete. Exchange leases were outstanding MLA leases that could be exchanged for a new lease under the Act of August 21, 1935, Public Law 74–295 § 2(a), 49 Stat. 674, 679. The August 8, 1946, Act eliminated the 1935 Act provisions for exchange leases, and the BLM no longer accepts these types of applications. Public Law 79–696 sec. 3, 60 Stat. 950, 951.

Section 3107.8 Renewal Leases

The proposed rule would eliminate §§ 3107.8–1 through 3107.8–3, which are the provisions related to renewal leases, in their entirety because they are obsolete. Renewal leases that had an expiration date after November 15, 1990, were eligible for a final renewal under the provisions of the November 15, 1990, Act, (for 10 years and for so long thereafter as oil and gas is produced in paying quantities). Public Law 101–567, 104 Stat. 2802. If a lease was renewed after the 1990 amendment and was not producing oil or gas at the end of its 10-year renewal term, the lease expired with no further option for renewal. The BLM no longer accepts these types of applications.

Section 3107.71 Payment of Compensatory Royalty

The proposed rule would redesignate this section from §§ 3107.9–1 to 3107.71 pursuant to the reorganization identified earlier.

Section 3107.72 Subsurface Storage of Oil and Gas

Instead of citing to 43 CFR 3105.5–4, the proposed rule would add the language from 43 CFR 3105.5–4 to this section. This change negates the need to refer to another section of the rule.

10. Section-by-Section Discussion for Changes to 43 CFR Subpart 3108

The proposed rule would remove one section and revise two section headings in the existing 43 CFR subpart 3108. The goal of the revisions is to replace the question-and-answer format and to remove obsolete language related to Class III reinstatements.

Section 3108.10 Relinquishment

The proposed rule would update the title from “As a lessee, may I relinquish my lease?” to read “Relinquishment.” The proposed rule would also change references to “you” to “the lessee(s).” In addition, the proposed rule would update paragraph (c) to allow either the BLM or the appropriate surface management agency to approve a plan for the reclamation of the oil and gas operations on a relinquished lease.

Section 3108.21 Automatic Termination

The proposed rule would update paragraph (b) to remove the phrase “bill rendered by the designated Service Office, or,” because the ONRR updated its policy in 2015 to eliminate the mailing of courtesy notices. The proposed rule would add a new paragraph (c) to incorporate caselaw providing that Congress intended the automatic termination provision of 30 U.S.C. 188 to apply to the regular, annual rental payment, the necessity for which a lessee had continuous notice, and that the automatic termination provision was not intended to apply to a case where a lessee had no way of knowing that the obligation had accrued, e.g., where a lease suspension is lifted or where the lease account reverts from a royalty to a rental status. See Husky Oil Company of Delaware Depco, Inc., 5 IBLA 7 (1972). This might happen where a lease suspension is lifted or where the leases were held by allocated production from an agreement and the agreement terminates, thus reverting the lease account from a royalty to a rental status. The new paragraph (c) would state that the automatic termination provision does not apply where, due to other contingencies such as a suspension being lifted or unit terminating, additional rental is due on a date other than the lease anniversary date and where the lessee did not receive notice that the obligation had accrued, unless the lessee fails to pay the rental within the period prescribed in the BLM notice.

Section 3108.22 Reinstatement at Existing Rental and Royalty Rates: Class I Reinstatements

The proposed rule would update paragraph (a)(2) to replace the reference to a postmark by the U.S. Postal Service with a reference to the ONRR's online rental payment system, since the ONRR updated its policy in 2015 to require only electronic rental payments. The proposed rule would move paragraph (d)—which provides that the BLM would not issue a new lease for lands that have been covered by a lease that terminated automatically until 90 days after the date of termination—to 43 CFR 3101.40(a). The intent is to ensure that this language is not overlooked by placing it more prominently with lease issuance provisions. The IRA did not make any changes to the grounds and conditions for Class I reinstatements.

Section 3108.23 Reinstatement at Higher Rental and Royalty Rates: Class II Reinstatements

To further implement the IRA, the proposed rule would update paragraph (a) so that the grounds for a Class II reinstatement only apply to competitive leases. The IRA explicitly rescinded the BLM's authority to approve Class II reinstatements for noncompetitive leases issued for public domain lands under the MLA and implicitly did the same for the MLAAL (by eliminating references to higher rental requirements for reinstated, noncompetitive leases). In any event, reinstatements are discretionary; had Congress not directed the BLM to eliminate reinstatement of noncompetitive leases under the MLAAL, the BLM has concluded that such reinstatements are not prudent because the grounds for a reinstatement should be based on the type of lease and not be based on the land status.

The proposed rule would eliminate the existing paragraph (b)(1) in its entirety. This provision addresses the timeliness of Class II reinstatement petitions for leases that terminated on or before August 8, 2005, and is no longer applicable. The proposed rule would update the proposed redesignated paragraph (b)(2)(iii) to remove the reference to funds held in escrow, as this is outdated. The BLM would not approve a reinstatement if the BLM does not collect all back rentals and royalties at the rates established in the reinstated lease, but the BLM would not require the funds to be held in escrow until a reinstatement is approved.

The proposed rule would move existing paragraph (c)—which states that the BLM will not issue a new lease for lands covered by a terminated lease until all action on the petition is final—to 43 CFR 3101.40(a). The intent is to ensure that this language is not overlooked by placing it more prominently with lease issuance provisions. The proposed rule would update the reference to the Committee on Interior and Insular Affairs (which no longer exists) to the current House Committee on Natural Resources. The proposed rule would remove existing paragraph (f), which refers to royalty reductions, as this language would already be covered under the proposed 43 CFR 3103.41(c).

Section 3108.2–4 Conversion of Unpatented Oil Placer Mining Claims: Class III Reinstatements (Existing Rule)

The purpose of the existing section is for converting unpatented oil placer mining claims validly located prior to February 24, 1920, to an oil and gas lease. The proposed rule would remove the language related to Class III reinstatements in its entirety because the IRA removed the authority for Class III reinstatements.

Section 3108.30 Cancellation

The proposed rule would update the last sentence in paragraph (a) to remove the phrase “after notice to the lessee in accordance with section 31(b) of the Act and only.” This phrase does not add anything to the existing regulation and has therefore led to confusion. The proposed rule would state instead that “The lease may be canceled only after default continues for 30 calendar days after a notice of default has been delivered in accordance with 43 CFR 1810.2.” The proposed rule would update paragraphs (b) and (c) to change the phrase from “by judicial proceedings” to “by court order” to align with the text found in 43 CFR 3136.3(b), bringing consistency to the regulations.

11. Section-by-Section Discussion for Changes to 43 CFR Subpart 3109

The proposed rule would not make any revisions to the section headings in the existing subpart 3109 regulations. This subpart covers the process for leasing lands under the provisions in 30 U.S.C. 301–306, which addresses leasing under railway and other rights-of-ways.

Section 3109.12 Application

The proposed rule would split the existing paragraph into four separate paragraphs by topic (no specific form is required, who can file, the filing fee, and what an application must include) for clarity. The proposed rule would also add a new requirement (proposed paragraph (d)(5)) that the applicant must include a map of the applicable lands, which would support the bidding process related to the lease or compensatory royalty agreement. In many cases, the adjacent mineral owners or lessees, who can bid upon the parcel, require a map to identify the lands. The requirement for the applicant to provide a map would reduce the cost to the public and would ensure that the BLM is reviewing the correct lands for a lease.

Section 3109.13 Notice

The proposed rule would update the phrase “a bid for the amount or percent of compensatory royalty” to read “a bid for the percent of compensatory royalty.” This change aligns with the BLM's existing process and reduces confusion.

Section 3109.15 Compensatory Royalty Agreement or Lease

The proposed rule would adjust the terms of a ROW lease to match the terms of a competitive lease issued under the MLA with respect to the rental, royalty, and primary term of the lease (10 years). The proposed rule would also specify for clarity that the provisions of 43 CFR part 3100 apply to the issuance and administration of leases for oil and gas deposits underlying a ROW issued under this part.

12. Section-by-Section Discussion for Changes to 43 CFR Part 3110

The proposed rule would remove the existing 43 CFR part 3110 in its entirety. The IRA removed the BLM's authority to issue a noncompetitive lease. The BLM is rejecting all pending noncompetitive lease applications received before enactment of the IRA.

13. Section-by-Section Discussion for Changes to 43 CFR Subpart 3120

The proposed rule would add two new sections and remove four sections in existing 43 CFR subpart 3120. The proposed rule would revise four section headings. The goal of the revisions is to streamline and provide clarity and consistency with other changes in this proposed rule.

Section 3120.11 Lands Available for Competitive Bidding

The proposed rule would update the introductory paragraph from “All lands available for leasing shall be offered” to “All lands eligible and available for leasing may be offered” to conform this section with the language of 30 U.S.C 226(a) and (b). This language will also better reflect Interior's statutory discretion to identify lands available for oil and gas leasing.

The proposed rule would update paragraph (a) to change the language from “Lands in oil and gas leases” to “Lands that were covered by previously issued oil and gas leases” to provide clarity.

The proposed rule would update paragraph (c) to clarify that a lease interest forfeited through a bankruptcy to the United States may be reoffered through a competitive auction.

The proposed rule would also revise existing paragraph (e) to reflect the IRA's removal of noncompetitive leasing.

The proposed rule would add a new paragraph (g) to implement provisions of the IRA by stating that lands offered in a previous sale for which no bids were accepted or received may be offered for competitive auction under this subpart. Prior to the IRA, these lands would have been eligible for noncompetitive leasing.

Section 3120.12 Requirements

The proposed rule would update paragraph (a) to conform this section with the language of 30 U.S.C 226(a) and (b). The proposed rule would update paragraph (b) to change “competitive oral or internet-based bidding process” to read “a competitive auction process.” A definition for competitive auction would be added to 43 CFR 3100.5 as explained previously.

The proposed rule would add a new paragraph (c) to codify existing policy and strengthen the bidder registration process. The MLA provides that leases may be issued only to a “responsible qualified bidder” (30 U.S.C. 226(b)(1)(A)). A bid submitted at a competitive auction represents a good-faith intention to acquire an oil and gas lease, and any winning bid constitutes a legally binding commitment to accept the lease and pay monies owed. Any bidder who has not paid the minimum monies owed on the day of sale is not a “responsible qualified bidder” and would be referred to the DOI's Office of the Inspector General, Administrative Remedies Division, for appropriate action, including potential suspension and debarment. Definitions for qualified bidder and responsible bidder would be added to 43 CFR 3100.5 as explained previously.

The proposed rule would redesignate the existing paragraph (c) to paragraph (d). The proposed rule would update this paragraph to refer to the increased national minimum bid of $10 per acre, or fraction thereof, in 43 CFR 3000.130. The cross-reference to § 3000.130 allows BLM to adjust the minimum bid regularly for inflation. The IRA raised the national minimum bid from $2 per acre to $10 per acre. Notably, the IRA specifically authorizes the Secretary to, at the conclusion of the 10-year period established by the statute, “establish by regulation a higher national minimum acceptable bid for all leases based upon a finding that such action is necessary: (i) To enhance financial returns to the United States; and (ii) to promote more efficient management of oil and gas resources on Federal lands.” The minimum acceptable bid is important because it establishes the starting bid at the BLM's oil and gas lease sale auctions.

Section 3120.13 Protests

The proposed rule would rename this section from “Protests and appeals” to “Protests” and would update the paragraphs in this section to change the term “appeal” to “protest.” This change reflects IBLA decisions providing that the current use of the term “appeal” is imprecise and creates confusion. Refer to Wyoming Outdoor Council, et al., 156 IBLA 377 (2002). The BLM's issuance of a Notice of Competitive Lease Sale is not an appealable action, because a notice merely distributes and communicates general information about a proposed action. The term “protest,” which is any objection raised by any person before an action is taken by the BLM, is the proper term. Appeals are covered under 43 CFR 3000.40 and do not need to be repeated in this section.

Section 3120.30 Nomination Process

The BLM is proposing to update the process by which it formally nominates parcels for sale at a competitive auction. The BLM is considering using this process for certain BLM state offices or for future leases sales and requests comments on whether the regulations should retain this process and, if so, what changes to the formal nomination process should be made.

In 1988, following the passage of FOOGLRA, the BLM published new oil and gas regulations that established two separate processes for leasing public lands: (1) the informal process, which primarily relies on EOIs from the public; and (2) the formal nomination process. 53 FR 22829 (“the final rulemaking provides administrative flexibility to allow for either informal EOIs or a formal nomination process to determine the lands offered competitively”). Aside from a few test sales following the enactment of FOOGLRA, the BLM has never employed the formal nomination process. See 53 FR 22829 (“the Director elects to permit informal expressions of interest to be submitted to the proper BLM office but declines at this time to employ formal nominations under 43 CFR 3120.30”). However, the existing regulations, as well as the BLM's current competitive leasing handbook, continue to provide for the use of the formal nomination process, following notice to the public in the Federal Register .

The BLM believes that aspects of this process could be used as a possible mechanism to implement the recommendations from the DOI's November 2021 “Report on the Federal Oil and Gas Leasing Program,” including “carefully consider[ing] what lands make the most sense to lease in terms of expected yields of oil and gas, prospects of earning a fair return for U.S. taxpayers, and conflicts with other uses” and “evaluat[ing] operational adjustments to its leasing program that will avoid nomination or leasing of low potential lands.” The proposed rule would update the following sections for the formal nomination process with the intent to make these nominations nonbinding as the BLM considered a nomination to be similar to the noncompetitive pre-sale leasing process, and the IRA removed the noncompetitive leasing process. In addition, the rule proposes to eliminate the allowance for unnominated parcels to become available for noncompetitive leasing.

Section 3120.31 General

The proposed rule would update this paragraph to remove the requirement that a nomination be submitted with a national minimum bid. The purpose of removing this requirement is to make formal nominations nonbinding. To provide the BLM with flexibility, this paragraph would also be updated to remove the citation to 43 CFR 3120.4; that would remove the requirement that a List of Lands Available for Competitive Nominations be posted in the same manner as the Notice of Competitive Lease Sale. This paragraph would also be updated to include language stating that nominations may be filed on a form or by a method approved by the Director, providing the BLM with flexibility and discretion to continue to improve the program (by, for example, allowing the public to send electronic nominations).

Section 3120.32 Filing of a Nomination for Competitive Leasing.

The proposed rule would revise the introductory paragraph under this section to state that nominations may be filed “on a form or using a method approved by the Director” similar to the change in § 3120.31 described earlier. The existing paragraph (b) would be revised to remove the second sentence referring to the execution of a nomination constituting a legally binding offer, due to the removal of the noncompetitive leasing process as prescribed by the IRA. The existing paragraph (c) would be updated to remove the reference to refunding all moneys if the nomination has not been completed or timely filed, since the administrative filing fees are nonrefundable. The existing paragraph (d) would be updated to remove the requirement that a nomination must be submitted with a minimum bid and first year rental to reflect the nonbinding nature of the nomination. Through these changes, the only fee that would be required to be submitted with a nomination is the nonrefundable, administrative filing fee, as specified in the proposed 43 CFR 3000.120.

Section 3120.3–3 Minimum Bid and Rental Remittance

The proposed rule would remove this existing section in its entirety, consistent with the changes made to the nomination process, to make formal nominations nonbinding.

Section 3120.3–4 Withdrawal of a Nomination

The proposed rule would remove this existing section in its entirety, consistent with the changes made to the nomination process, to make formal nominations nonbinding.

Section 3120.33 Parcels Receiving Nominations

The proposed rule would redesignate this section from 43 CFR 3120.3–5 to 43 CFR 3120.33 due to the proposed removal of the sections preceding this one. The language for parcels receiving nominations would be updated to use “may” (rather than “shall”) be included in a Notice of Competitive Lease Sale to be consistent with the BLM's statutory discretion to lease.

Section 3120.3–6 Parcels Not Receiving Nominations

The proposed rule would remove this section in its entirety, due to the removal of the noncompetitive leasing process, consistent with changes made by the IRA.

Section 3120.3–7 Refund

The proposed rule would remove this section because the minimum bid and first year's rental would not be required for nominations, as explained earlier. The administrative filing fees found under the proposed 43 CFR 3000.120 are nonrefundable and would not be refunded to nominators who are unsuccessful at the competitive auction.

Expression of Interest

The proposed rule would add a new heading, “Expression of Interest,” to include rules for receiving EOIs for competitive leasing.

Section 3120.41 Process

The proposed rule would add requirements for submitting an EOI to the BLM. Paragraph (a) would state that a party submitting an EOI must include the submitter's name and address and must submit the EOI through the BLM's online leasing system. The National Fluids Lease Sale System (NFLSS) supports BLM administration of the leasing program for Federal onshore oil and gas and geothermal leasing. Using the NFLSS for the submittal of EOIs gives the BLM the capability for real-time reporting, which can streamline the leasing process and reduce the BLM's costs by (1) eliminating data entry by BLM staff, placing the onus for correct EOI submissions on the submitter; (2) automatically publishing EOIs in the NFLSS, which facilitates transparency of the EOI process; and (3) supporting the BLM's communication with submitters by allowing them to track the status of their EOIs through the NFLSS.

Paragraph (b) would require the use of legal land descriptions in EOIs. The scenarios cover: (1) lands surveyed under the public land survey system; (2) unsurveyed lands; (3) lands approved by protracted surveys; (4) lands that have water boundaries; (5) fractional mineral interest in lands; and (5) fractional interest lands. The proposed rule would add the requirement under paragraph (b)(6) that the submitter provide the surface owner information for split estate lands to reflect current policy in Handbook H–3120–1, Competitive Leases, and add paragraph (7) to allow the BLM to accept an acquisition or tract number in lieu of the legal land description, if it constitutes an adequate description of the lands.

Paragraph (c) would allow the submission of more than one EOI by a submitter, so long as each expression separately satisfies the requirements of paragraph (b).

Paragraph (d) would state that each EOI must include the filing fee set out in the proposed 43 CFR 3000.120.

Paragraph (e) would allow the BLM to include lands in a lease sale on its own initiative.

Paragraph (f) would state that, when determining whether the BLM should offer lands specified in an EOI at a lease sale, the BLM would evaluate the Secretary's obligations to manage public lands for multiple use and sustained yield and to take any action required to prevent unnecessary or undue degradation of the lands and their resources, along with other applicable legal requirements. At a minimum, the BLM would consider: (1) proximity to oil and gas development existing at the time of the BLM's evaluation, giving preference to lands upon which a prudent operator would seek to expand existing operations; (2) the presence of important fish and wildlife habitats, including wetland habitats, or connectivity areas, giving preference to lands that would not impair the proper functioning of such habitats or corridors; (3) the presence of historical properties, sacred sites, and other high-value leasing lands, giving preference to lands that would not impair the cultural significance of such resources; (4) the presence of recreation and other important uses or resources, giving preference to lands that would not impair the value of such uses or resources; and (5) the potential for oil and gas development, giving preference to lands with high potential for development.

Although paragraph (f) lists specific criteria for the BLM to review, the listed criteria do not limit the BLM's authority to fulfill its legal obligations under FLPMA, NEPA, and MLA. The BLM would consider additional criteria and factors when evaluating parcels for a lease sale. The BLM requests comments on additional criteria the BLM might consider when giving preference to leasing parcels. Should this rule include among the listed criteria compliance with the goals and objectives of applicable land use plans and protecting communities with environmental justice concerns? How can the rule better achieve the BLM's intent to give preference to leasing parcels where development would have less impacts on nearby communities?

The BLM proposes that promulgating rules for this EOI preference process would provide a mechanism for implementing the recommendations from the DOI's “Report on the Federal Oil and Gas Leasing Program,” including the recommendation to “carefully consider what lands make the most sense to lease in terms of expected yields of oil and gas, prospects of earning a fair return for U.S. taxpayers, and conflicts with other uses” and to “evaluate operational adjustments to its leasing program that will avoid nomination or leasing of low potential lands.” This process would ensure that oil and gas leasing on public lands occurs in a way that is consistent and deliberate, focus development where there is the most potential for recovery, and allow the agency to manage public lands for other uses as well, including conservation and restoration of wildlife habitat. For example, offering leases where current infrastructure exists should reduce the overall footprint of energy development and limit wildlife impacts and habitat fragmentation. Giving preference to leasing outside of important wildlife habitat would help to ensure that important seasonal ranges remain connected, and that species can access important resources undeterred as they move across the landscape.

The BLM would implement this EOI preference process to conserve certain public lands while ensuring the American taxpayer receives a fair return and meeting the energy demands of the future. The BLM does not intend that parcels must meet all five of the preference criteria in order to be available for leasing, and the term “preference” should not be interpreted to mean “absolute.” The BLM recognizes the need for balance and for the preference criteria to be situational and considered on a case-by-case basis. The preference criteria generally would be applied before the NEPA analysis is completed. A summary of how the criteria apply would be included for public comment. The BLM could then take the public comments into account when considering current and future sales.

The BLM requests comments addressing whether or how the preference criteria should be applied when the Federal surface lands are administered by another Federal agency. For example, in National Forest System lands, the Forest Service typically prepares a pre-leasing NEPA analysis that the BLM subsequently relies upon when making its leasing determination.

Paragraph (g) would allow the BLM to reconfigure the lands that are included in an expression of interest in the parcels that the BLM offers for sale.

Section 3120.42 Agency Inventory of Leasing

The proposed rule would add this new section to provide that periodically the BLM will calculate the acreage for which EOIs have been submitted in the previous year, along with the total acreage offered for lease. This would clarify how the BLM will comply with section 50265 of the IRA, consistent with Instruction Memorandum 2023–006, Implementation of Section 50265 in the Inflation Reduction Act for Expressions of Interest for Oil and Gas Lease Sales. The BLM requests public comments on this point.

Section 3120.50 Notice of Competitive Lease Sale

The proposed rule would redesignate this section from 43 CFR 3120.4 to 43 CFR 3120.50 per the previously mentioned reorganization.

Section 3120.51 General

The proposed rule would redesignate this section from 43 CFR 3120.4–1 to 43 CFR 3120.51 per the previously mentioned reorganization.

Section 3120.52 Posting Timeframes

The proposed rule would revise the title of this section from “Posting of notice” to “Posting timeframes.” The proposed rule would add a new paragraph (a), providing that, after identifying a preliminary list of lands for a lease sale, the BLM would provide a scoping period, of not less than 30 calendar days, for public comment. The BLM uses preliminary parcel lists to roughly organize potential parcels for sale and to initiate environmental review. While the BLM invites public feedback on the parcel list, preliminary parcel lists do not constitute an official notice of a proposed BLM action or final action and are not subject to protests or appeals.

The proposed rule would add a new paragraph (b) providing that, after drafting a preliminary NEPA document for a lease sale, the BLM would provide a comment period, not less than 30 calendar days. Similar to preliminary parcel lists, preliminary NEPA documents do not constitute an official notice of a proposed BLM action or a final action and are not subject to protests or appeals.

The proposed rule would add a new paragraph (c) providing that the BLM would post the Notice of Competitive Lease Sale at least 60 calendar days prior to the sale and would make available to the public a list of lands to be offered for competitive sale. This is an additional 15 calendar days from the BLM's current practice. The extended posting timeframe would provide the BLM more time to resolve protests prior to any proposed lease sale. The BLM routinely receives one or more protests on posted sale offerings, but it often does not receive the protests until shortly before or on the morning of the protest deadline. The BLM state offices need a reasonable amount of time to review the reasons for the protest in advance of the sale and decide if withdrawing the protested parcel from the sale is appropriate. Consequently, in new paragraph (d), the BLM would provide that the protest period is allowed only for the first 30 days that the sale notice is posted to provide the second 30 days as the time in which the BLM would review protests.

The proposed rule would also remove the requirement for the notice to be posted in the BLM office or any surface managing agency office. In the BLM's experience, the public finds information concerning Notices of Competitive Lease Sale through the NFLSS or on the individual state office web page, rather than a posted sale notice in the individual offices. The BLM believes that remaining silent in the regulations on how the sale notice would be made available to the public allows the BLM the flexibility and discretion to continue to improve the program. This silence, however, does not in any way abnegate any applicable legal obligations to provide notice in the first instance.

The proposed rule would also add a new paragraph (d) to state that the BLM would provide a protest period, of not less than 30 days, for public input on the upcoming lease sale during the first 30 days of the 60-day public notice period provided for in paragraph (c) earlier. Establishing a deadline for filing protests ensures an orderly and efficient leasing process. Finally, the proposed rule would add a new paragraph (e) to state that “the BLM will make available the final NEPA compliance documents prior to issuing a lease from the lease sale.” The BLM plans to post the NEPA compliance documents on ePlanning, but the proposed rule would not codify that practice so that BLM retains flexibility for future sales.

Competitive Auction

The proposed rule would redesignate this section from 43 CFR 3120.5 to remove the regulatory section number, as this is a heading that has no text associated it. The proposed rule would revise the title of this section from “Competitive sale” to “Competitive auction,” consistent with the proposed definition.

Section 3120.61 Competitive Auction

The proposed rule would redesignate this section from 43 CFR 3120.5–1 to 43 CFR 3120.61 due to the previously mentioned reorganization. The proposed rule would rename this section from “Oral or internet-based auction” to “Competitive auction” and update the paragraphs in this section to replace the reference to oral or internet-based bidding with the term “competitive auction,” consistent with the proposed definition.

Paragraph (a) would also be updated to remove the reference to the formal nominations process, consistent with the changes made to the nomination process.

For this same reason, paragraph (c) would be removed in its entirety.

Section 3120.62 Payments Required

The proposed rule would redesignate this section from 43 CFR 3120.5–2 to 43 CFR 3120.62 due to the previously mentioned reorganization.

The proposed rule would update paragraph (b)(1) to increase the minimum bonus bid to reference 43 CFR 3000.130, consistent with the change described earlier in the proposed 43 CFR 3120.12.

The proposed rule would update paragraph (c) to replace “10 working days” with “10 business days” and would replace the reference to “oral or internet-based auction” with the term “competitive auction.”

Section 3120.63 Award of Lease

The proposed rule would redesignate this section from 43 CFR 3120.5–3 to 43 CFR 3120.63 due to the previously mentioned reorganization.

The proposed rule would update paragraph (c) to remove the reference to noncompetitive offers, consistent with the proposed removal of 43 CFR part 3110.

The proposed rule would revise paragraph (d) to remove the reference to noncompetitive lease offers as required by the IRA. The proposed rule would update Paragraph (d) to require the BLM to resolve all protests covering the lands to be leased prior to issuing a lease to comport with the BLM's longstanding policy not to issue a lease until all protests covering the lands to be leased have been resolved by the BLM.

Finally, the proposed rule would add a statement that leases would be issued within 60 calendar days following resolution of any protests not resolved prior to the sale and payment by the successful bidder of the remainder of the bonus bid, if any, and the annual rental for the first lease year. This text corresponds to the provisions in the MLA at 30 U.S.C. 226(b)(1)(A). The proposed rule would also add to paragraph (e) a provision stating that, if the BLM cannot issue the lease within 60 days, the BLM may reject the offer. The BLM has received an increased number of protests and legal challenges to its decision to offer lands for lease or issue leases. These protests and challenges may require the BLM to complete a corrective environmental analysis to reach resolution. The protests, challenges, and new analysis can lead to lengthy delays after the sale before the BLM can issue the lease, with the BLM holding the first-year rentals and bonus bids collected from the sales. In these cases, the BLM's policy is to reach out to the successful bidder to see if they want to decline the lease or continue to wait until there is a resolution. If the successful bidder declines the lease, the BLM would reject the lease offer.

Section 3120.70 Parcels Not Bid on at Auction

The proposed rule would redesignate this section from 43 CFR 3120.6 to 43 CFR 3120.70 due to the previously mentioned reorganization. The proposed rule would update the paragraph to replace the reference to “oral or internet-based” auction with the term “competitive auction,” consistent with the changes made earlier in this subpart. The section would also remove references to noncompetitive leases pursuant to the IRA and would provide that parcels not bid on at auction would be available for future competitive sale.

Section 3120.80 Future Interest

The proposed rule would redesignate this section from 43 CFR 3120.7 to 43 CFR 3120.80 due to the previously mentioned reorganization.

Section 3120.81 Nomination or Expression of Interest To Make Lands Available for Competitive Lease

The proposed rule would redesignate this section from 43 CFR 3120.7–1 to 43 CFR 3120.81 due to the previously mentioned reorganization. The proposed rule would update the title and paragraph of this section from “Nomination” to “Nomination or Expression of Interest to make lands available for competitive lease,” consistent with the changes made in this subpart.

Section 3120.82 Future Interest Terms and Conditions

The proposed rule would redesignate this section from 43 CFR 3120.7–2 to 43 CFR 3120.82 due to the previously mentioned reorganization.

Section 3120.83 Compensatory Royalty Agreements

The proposed rule would redesignate this section from 43 CFR 3120.7–3 to 43 CFR 3120.82 due to the previously mentioned reorganization.

14. Section-by-Section Discussion for Changes to 43 CFR Subpart 3137

The proposed rule would revise two of the sections and their headings in the existing subpart 3137 regulations. The purpose of updating these sections is to add the processing fees for unit applications and successor operators.

Section 3137.23 NPR–A Unitization Application

The proposed rule would update the title from “What must I include in my NPR–A unitization application?” to “NPR–A unitization application.” The proposed rule would update paragraphs (d)(1) and (4) to change “you” to “the operator.” This is intended to clarify who “you” is in this section. The proposed rule would add a new paragraph (i) to include the required new processing fee for unit agreement applications found in the fee schedule in 43 CFR 3000.120 of this chapter.

Section 3137.61 Change in Unit Operators

The proposed rule would update the title from “How do I change unit operators?” to “Change in unit operators.” The proposed rule would update paragraph (a)(1)(i) by changing “It” to “The new operator.” This is intended to clarify who “it” references in this section. The proposed rule would add a new paragraph (a)(3) to include the required new processing fee for designation of a successor operator found in the fee schedule in 43 CFR 3000.120 of this chapter.

15. Section-by-Section Discussion for Changes to 43 CFR Subpart 3138

The proposed rule would revise one section and its headings in the existing 43 CFR subpart 3138 regulations. The purpose of updating this section is to add the processing fee for subsurface storage agreement.

Section 3138.11 Applications for a Subsurface Storage Agreement

The proposed rule would revise the title from “How do I apply for a subsurface storage agreement?” to “Applications for a subsurface storage agreement.” The proposed rule would update paragraphs (a)(6), (b), and (c) to change “you” to “the operator.” This is intended to clarify who “you” references in this section. The proposed rule would add a new paragraph (a)(12) to include the required new processing fee for subsurface gas storage agreement applications found in the fee schedule in 43 CFR 3000.120 of this chapter.

16. Section-by-Section Discussion for Changes to 43 CFR Subpart 3140

The proposed rule would not make any revisions to the section headings in the existing 43 CFR subpart 3140 regulations.

Section 3140.5 Definitions

The BLM is proposing to alphabetize the definitions in this section.

Section 3140.11 Existing Rights

The proposed rule would update paragraph (a) to state the application time period ended on November 15, 1983. These regulations are not proposed for elimination because the BLM is still processing applications. The BLM has been working on the planning efforts surrounding the special tar sand areas and the environmental analysis under NEPA to support the conversion to a combined hydrocarbon lease. This process has delayed the BLM in issuing decisions related to the applications.

Section 3140.12 Notice of Intent To Convert

The proposed rule would update paragraphs (a) and (c) to have the specific effective date of November 15, 1983, to ensure there is no confusion related to this rulemaking. In addition, the language in this section would be updated to past tense.

Section 3140.14 Other Provisions

The proposed rule would increase the rental rate in paragraph (b) from $2 per acre to the annual rental, as specified in 43 CFR 3000.130, consistent with the rental increases in this proposed rule.

The proposed rule would update paragraph (c)(2) to update the royalty rate for a combined hydrocarbon lease from 12.5 percent to 16.67 percent to implement provisions of the IRA. The proposed rule would update paragraph (c)(3) to clarify that the royalty rate reduction requested for tar sands will not apply to the oil and gas and vice versa. Due to the different methods to extract tar sands versus oil and gas, the lessee may need a royalty rate reduction for one resource to continue operations and no royalty rate reduction for another resource.

Section 3140.23 Application Requirements

The proposed rule would update paragraph (a) to clarify that the application window has closed. The remaining paragraphs under this section would remain unchanged because the BLM continues to process applications; however, the BLM proposed to update the language to past tense.

Section 3140.42 Issuance of the Combined Hydrocarbon Lease

The proposed rule would update paragraph (d) to state that the BLM would issue one combined hydrocarbon lease to cover the existing oil and gas lease or valid claim based on mineral locations which have been approved for conversion within the special tar sand area. The existing paragraph (d)(2) is eliminated in its entirety as the BLM would not issue a combined hydrocarbon lease covering multiple oil and gas leases. Together, these changes permit the existing lease to be converted to a combined hydrocarbon lease without changes to the legal land description or leased area. The BLM believes that converting multiple leases into a combined hydrocarbon lease is not necessary, because combined hydrocarbon leases can be unitized. Unitization allows for the joining together of large areas such as an entire reservoir or field to optimize operations. Existing combined hydrocarbon leases have already been unitized, and the BLM believes there is no need to maintain the conversion of multiple leases in the regulations.

Section 3140.50 Duration of the Lease

The proposed rule would update the paragraph in this section to state that if the applicant withdraws the combined hydrocarbon lease application or the BLM denies the conversion application, the suspension on the oil and gas lease would be lifted and the term would be adjusted by the time remaining on the term of the lease.

Section 3140.70 Lands Within the National Park System

The proposed rule would update the paragraph in this section to make it clear that the conversion application window closed in 1983, consistent with the previously described proposed changes.

17. Section-by-Section Discussion for Changes to 43 CFR Subpart 3141

The proposed rule would not make any revisions to section headings in the existing 43 CFR subpart 3141 regulations.

Section 3141.10 General

The proposed rule would update paragraph (b) to remove the reference to noncompetitive leasing, as described in 43 CFR subpart 3110. This change is consistent with the implementation of the IRA. The proposed rule would update paragraph (g) to increase the minimum acceptable bid from $2 per acre to reference the minimum bid in 43 CFR 3000.130, consistent with the change described earlier in 43 CFR 3120.12.

Section 3141.22 Exploration Licenses

The proposed rule would update paragraph (b)(2) to refer to the fee schedule in 43 CFR 3000.120. The proposed rule would update paragraph (b)(4) to remove the triplicate filing requirement. The proposed rule would update paragraph (e)(2) to increase the rental from $2 per acre for new oil and gas leases issued after August 16, 2022, to the rental rate in 43 CFR 3000.130, consistent with the requirements of the IRA.

Section 3141.52 Term of Lease

The proposed rule would update paragraph (a) to clarify that this section pertains to the primary term of oil and gas leases in special tar sands areas.

Section 3141.53 Royalties and Rentals

The proposed rule would increase the royalty in paragraph (a) from 12.5 percent to 16.67 percent and change the reference from the “Minerals Management Service” to the “ONRR,” consistent with the other changes in this proposed rule and the IRA.

The proposed rule would update paragraph (b) to reference the oil shale lease procedures for reducing the royalty rate applicable to a tar sand lease prior to the commencement of commercial operations, currently at 43 CFR 3903.54. The BLM considers the current regulations to be unclear on which procedures to reference to reduce the royalty rate applicable to a tar sand lease prior to the commencement of commercial operations.

The proposed rule would update paragraph (c) to simply state that the annual rental for all combined hydrocarbon leases is as stated in the lease. The BLM will increase the rentals for combined hydrocarbon leases issued after the effective date of the final rule using 43 CFR 3000.130 for the rental rate, consistent with the changes described previously.

The proposed rule would likewise update paragraph (d) to simply state that the annual rental for all tar sand leases is as stated in the lease. The BLM will increase the rentals for tar sand leases issued after the effective date of the final rule using 43 CFR 3000.130 for the rental rate, consistent with the changes described previously.

Section 3141.62 Publication of a Notice of Competitive Lease Offering

The proposed rule would remove paragraph (a) in its entirety, eliminating the requirement that the BLM publish a lease sale notice in the Federal Register and in a newspaper and providing the BLM with flexibility when determining the appropriate notice method. The remaining paragraph in this section, which refers to making a sale notice available to the public, would be extended to combined hydrocarbon leases in addition to the tar sand and oil and gas leases listed in this paragraph. The proposed rule would change the remaining paragraph to make the Notice of Competitive Lease Sale requirements consistent with the proposed 43 CFR 3120.61 requirements.

Section 3141.63 Conduct of Sales

The proposed rule would eliminate paragraph (a) in its entirety and update the proposed paragraph (b) so there is a single consistent approach for conducting lease sales by competitive auction for both combined hydrocarbon leases and tar sand leases. This change would remove the written sealed bid approach for combined hydrocarbon leases.

The proposed paragraph (b)(2) would be updated to increase the minimum bonus bids for combined hydrocarbon leases and tar sand leases issued after the effective date of the final rule, and it moves the bids to 43 CFR 3000.130 for the Fiscal Terms of New Leases, consistent with the changes described earlier. Finally, the BLM proposes to set the minimum bonus bid for hydrocarbon leases based upon an economic evaluation, which the BLM will complete prior to holding a competitive sale for a hydrocarbon lease.

Section 3141.65 Rejection of Bid

The proposed rule would eliminate existing § 3141.6–4. Since the BLM would hold competitive auctions in a similar manner for oil and gas leases, tar sand leases, and hydrocarbon leases and would use the economic analysis to set the minimum bonus bid, the BLM would not need to reject a bid based upon the fair market value. The reference to the “one-fifth bonus” was changed to “minimum bonus” as needed to reflect the proposed changes to have a consistent sale approach for both tar sand leases and hydrocarbon leases.

Section 3141.70 Award of Lease

The proposed rule would eliminate the requirement for triplicate copies of the lease forms to be executed by the successful bidder. In addition, the proposed rule would update this section to specify the 30th “calendar day” in order to reduce confusion.

18. Section-by-Section Discussion for Changes to 43 CFR Subpart 3142

The proposed rule would rename the title of this subpart from “Paying Quantities/Diligent Development for Combined Hydrocarbon Leases” to “Paying Quantities/Diligent Development for Combined Hydrocarbon and Tar Sand Leases.” The proposed rule would not make any revisions to the section headings in the existing 43 CFR subpart 3142 regulations.

Section 3142.1 Purpose

The proposed rule would add “and tar sand leases” so that this subpart applies to both combined hydrocarbon and tar sand leases.

Section 3142.5 Definitions

The proposed rule would amend the first defined term to be “Production in paying quantities for combined hydrocarbon leases.” The proposed rule would add definitions for the terms “Production in paying quantities for oil and gas leases” and “Production in paying quantities for tar sand leases.”

Section 3142.21 Minimum Production Schedule

The proposed rule would add a new paragraph (b) to specify that the minimum annual tar sand production schedule for the lease or unit operations would be set at an economical level. The proposed new paragraph (b) would also state that, if the operator or lessee cannot establish economic production, the lease would terminate at the end of the lease's primary term.

19. Section-by-Section Discussion for Changes to 43 CFR Subpart 3151

The proposed rule would revise § 3151.10 and add a new § 3151.30. The BLM proposes these changes to protect the fiscal and scientific interests of the American public by ensuring the BLM has adequate cost recovery mechanisms for geophysical exploration permits and that it has access to the information obtained by the permittees.

Section 3151.10 Notice of Intent To Conduct Oil and Gas Geophysical Exploration Operations

The introductory paragraph would be updated to include the requirement for the filing fee.

Section 3151.30 Collection and Submission of Data

The proposed rule would add a new section entitled “Collection and submission of data” that would require the permittee to submit to the BLM all data and information obtained from the exploration permit. This new requirement is consistent with exploration permits carried out in Alaska, as set forth in the existing regulations at 43 CFR 3152.6.

20. Section-by-Section Discussion for Changes to 43 CFR Subpart 3160

The proposed rule would not make any revisions to the numbering or section headings in the existing 43 CFR 3160.0–5 regulations.

Section 3160.0–5 Definitions

The BLM is proposing to modify the existing definition for “New or resumed production under section 102(b)(3) of the Federal Oil and Gas Royalty Management Act.” The revised definition would remove the sentence describing circumstances in which a gas well would be considered to have been off of production, providing consistency in the BLM's management of both oil wells (which does not include this language) and gas wells. The BLM is proposing to add a new requirement for operators to notify the BLM when they shut-in a gas well, as described in greater detail under the proposed changes for 43 CFR 3162.3–4. The potential amount of plugging and remediation liability related to long-term shut-in wells is often difficult to identify. The update would therefore require operators to notify the BLM when it is shutting in a well and would allow the BLM to adequately track and evaluate the risk of nonproducing wells.

The BLM proposes new definitions for “Shut-in well” and “Temporarily abandoned well.” These definitions would clarify the terms for the new proposed requirements. The definition would describe a “Shut-in well” as a nonoperational well that can physically and mechanically operate by opening valves or activating existing equipment. The definition would describe a “Temporarily abandoned well” as a nonoperational well that is not physically or mechanically capable of production or injection without additional equipment or without servicing the well, but that may have future beneficial use.

These definitions were pulled from the BLM's existing policy and are similar to existing industry standard definitions for the two well statuses. The International Association of Drilling Contractors (IADC) and the Alaska Oil and Gas Conservation Commission defines “shut in” as “to close a well's surface, wellhead, or subsurface valves to halt flow from or into the well, with the completion interval remaining open to the tubing below the closed valve” (see https://iadclexicon.org/shut-in/ ). The IADC and the Colorado Oil and Gas Conservation Commission defines “temporarily abandoned well” to “mean a well which is incapable of production or injection without the addition of one or more pieces of wellhead or other equipment, including valves, tubing, rods, pumps, heater-treaters, separators, dehydrators, compressors, piping or tanks” (see https://iadclexicon.org/temporarily-abandoned-well/ ). The BLM proposes to add the statement “may have future beneficial use” into the temporarily abandoned well definition to clarify that the BLM expects an operator to promptly plug a well without future beneficial use. In some cases, the operator could use a nonproductive well bore for enhanced recovery operations or water disposal, even though the well cannot produce hydrocarbons.

21. Section-by-Section Discussion for Changes to 43 CFR Subpart 3162

The proposed rule would not make any revisions to the numbering or section headings in the existing 43 CFR 3162.3–4 regulations.

Section 3162.3–4 Well Abandonment

The proposed rule would modify paragraph (c) to state that no well may be temporarily abandoned for more than 30 days without the prior approval of the authorized officer and unless the operator provides adequate and detailed justification for the abandonment, verifies the mechanical integrity of the wells, and isolates the completed interval(s). The BLM would not accept vague assertations that the well may produce. See Goldmark Engineering, Inc., 146 IBLA 225, 227 (1998). The BLM requests comments on whether a temporary abandonment should trigger a bond review in addition to the adequate and detailed justification for the abandonment.

In addition, except in extraordinary circumstances, the proposed rule would provide that the maximum period of time for an operator to delay permanent abandonment of a temporarily abandoned well would not exceed 4 years. The Energy Policy Act of 2005, as amended by the IIJA, defines an idled well as “a well that has been nonoperational for at least 4 years and for which there is no anticipated beneficial use” (see 42 U.S.C. 15907). Therefore, to help avoid wells becoming idled in the first place, the BLM is proposing new reporting and operational requirements for operators of temporarily abandoned wells. When an operator does not address a temporarily abandoned well by returning the well to production in paying quantities ( i.e., production sufficient to cover the operator's operational costs) or plugging and permanently abandoning the well, historical data available to the BLM indicates that such wells are at an increased risk of becoming orphaned.

The proposed rule would add a new paragraph (d) outlining new requirements for operators of shut-in wells. Paragraph (d)(1) would require notification to the BLM of the well's shut-in status and shut-in date within 90 days of well shut-in. Paragraph (d)(2) would require, within 3 years of well shut-in, the operator to provide the authorized officer with verification of the mechanical integrity of the well and confirmation that the well remains capable of producing in paying quantities. Currently, an operator is not required to inform the BLM when they shut-in a well, and these additions would allow the BLM to better track its shut-in well inventory and to take proactive steps to ensure that those wells do not become idled, as directed by Congress at 42 U.S.C. 15907.

The proposed rule would add a paragraph (d)(3) stating that, within 4 years of well shut-in, the operator must: (i) permanently abandon the well; (ii) resume production in paying quantities; or (iii) provide the authorized officer with a detailed plan and timeline for future beneficial use for the well. The proposed rule would further provide that if the BLM determines that there is a legitimate future beneficial use for the well, it may allow the operator to delay permanent abandonment by 1 year. The proposed rule would provide that the authorized officer may grant additional delays in 1-year increments, provided that the operator confirms the future beneficial use of the well and is making verifiable progress on returning the well to a beneficial use. The BLM believes these new requirements with yearly interval checks would help operators manage shut-in wells, preventing them from becoming orphaned in the future.

22. Section-by-Section Discussion for Changes to 43 CFR Subpart 3165.1

The proposed rule would revise the 43 CFR 3165.1 heading from “Relief from operating and producing requirements” to “Relief from operating and/or producing requirements.”

Section 3165.1 Relief From Operating and/or Producing Requirements

The purpose of this section is to describe the requirements for lease suspension applications. The BLM proposes to update this section to encourage diligent development of leased lands and ensure lease suspensions are justified and tied to an end date. The BLM is proposing to modify paragraph (b) to clarify who may apply for a lease suspension.

The proposed rule would add a new paragraph (c) to state the BLM would not approve an application for a suspension of a lease in circumstances where an APD on the subject lease is filed less than 90 calendar days before the expiration date of the lease. Applications for lease suspensions are often filed late in the primary term of a lease. Although lessees and operating rights owners are entitled to the full primary term of the lease, they are also responsible for timely filing required plans and necessary applications. Lessees and operating rights owners should not assume the BLM will grant a suspension merely to relieve them of their obligations of diligence and timeliness when complying with these and related requirements. See Vaquero Energy Inc., 185 IBLA 233, 237 (2015). On average, the BLM requires 90 days to complete the required reviews and analysis before issuing a decision on an APD. This change would encourage lessees and operators to diligently pursue development when APDs are filed with the BLM near the end of the primary term of the lease; otherwise, the lease would expire.

The proposed rule would also update the proposed paragraph (d) to ensure lease suspensions would not exceed 1 year when they are requested by the operator. If the circumstances that warranted the suspension are still applicable, a request to extend the suspension prior to the lifting date of the suspension would be required.

The proposed rule would add a new paragraph (e) to state that BLM-directed suspensions may exceed 1 year.

The proposed rule would add a new paragraph (f) to state that lease suspensions would lift when they are no longer justified, when lifting the suspension is in the public interest of the lessor, or as stated in the approval letter. The BLM requests comments on the best approach for making determinations on lease suspensions that would reduce the cost to the American public and encourage diligent development of leased lands. In June 2018, the GAO issued a final report entitled, “BLM Could Improve Oversight of Lease Suspensions with Better Data and Monitoring Procedures” (GAO–18–411). In summary, oil and gas leases on Federal lands generate billions of dollars in rents and royalty payments each year, but these revenues decline if leases are suspended ( i.e., the lease term is placed on hold). In response to GAO recommendations, the BLM issued policy guidance requiring the BLM state offices to regularly review suspended leases and monitor lease suspensions to ensure that lease suspensions in effect are warranted. The BLM believes the proposed additions and updates are warranted to ensure lease suspensions are justified and tied to an end date.

23. Section-by-Section Discussion for Changes to 43 CFR Subpart 3171

The proposed rule would not make any revisions to the numbering or section headings in the existing 43 CFR subpart 3171.6 regulations.

Section 3171.6 Components of a Complete APD Package

The proposed rule would update the existing paragraph (b)(1)(i) to replace the phrase “referenced to the National Spatial Reference System, North American Datum 1983 or latest edition” with the phrase “generated by an electronic navigation system, and document the datum referenced to generate these coordinates.” The BLM is proposing this change to modernize the existing language that dates to 2007 and avoid the need to incorporate by reference the National Spatial Reference System, North American Datum 1983.

Section 3171.14 Valid Period of Approved APD

The proposed rule would not make any revisions to the numbering or section headings in the existing subpart 43 CFR 3171.14 regulations and proposes to adjust the valid period of time for approved APDs and address instances when an operator does not drill to total depth.

The BLM reviewed the number of APD extensions granted in the past and estimates that operators request extensions on approximately 33 percent or one-third of the APDs approved. The BLM approved 4,859 APDs in FY 2021 and expects to receive approximately 1,600 APD extension requests in FY 2023. This would result in an estimated 3,800 hours of BLM staff time and $136,000 annually to process APD extension requests, based upon an average processing time of 2.4 hours and processing cost of $85 per APD extension application. Therefore, the BLM proposes adjusting the valid period of time for approved APDs to reduce the cost to the American public and encourage diligent development of leased lands.

To find the correct approach, the BLM reviewed the timeframe for operators to drill an approved APD based on well spuds from calendar year 2015 through calendar year 2021. On average, an operator spuds a Federal well 0.78 years after APD approval. Based on the data reviewed, 74 percent of the wells were spud in the first year after APD approval, 15 percent of the wells were spud in the second year after APD approval, 6 percent of the wells were spud in the third year after APD approval, and 5 percent of the wells were spud in fourth year after APD approval. Therefore, because APD approvals are ordinarily valid for 2 years, only 11 percent of the wells spud required an APD extension approval from the BLM.

The BLM also reviewed the valid period for State permits to drill based upon State regulations or conditions tied to the permits. The State permits are valid for different times depending on the state; however, the time frame ranges from 6 months to 2 years with some states granting extensions and some states requiring the operator to resubmit the APD for a new permit if the well is not drilled. The BLM summarizes the State's permit to drill terms in the following table:

Therefore, the BLM is considering changes to this section and is requesting comments on the best approach to adjust APD extensions that would reduce the cost to the American public and encourage diligent development of leased lands. The BLM is considering two options. The first option would involve removing the option to extend APDs and changing the APD term from 2 years to 3 years. The second option would retain the 2-year APD term with a potential for a 1-year extension. The BLM would require a filing fee based upon the required review in Instruction Memorandum 2023–011, Approved Application for Permit to Drill Extensions, and incorporate this policy for APD extensions into the regulations. Either option would continue to allow operators to spud 95 percent of the wells approved in the initial APD based upon the current time between APD approval and well spud. If the operator does not drill the APD in the time provided, then the operator would need to apply for a new APD.

At this time, the BLM is proposing the first option to change the APD term from 2 years to 3 years with no extensions to reduce the administrative burden. This would reduce the cost for both the American public and the operators by eliminating the need for operators to file and BLM to review applications for APD extensions. The current proposal would update the existing paragraph (a) to state that an APD is valid for 3 years. The BLM proposes to remove the sentence describing the 2-year extension.

The BLM is proposing to add two new paragraphs to this section to address the many partially drilled and uncompleted wells remaining on Federal lands and to require operators to comply with the approved APD prior to the permit's expiration date. Under the BLM's current regulations, operators can spud wells near the APD's expiration date by setting conductor or surface casing. The operators could then extend past the APD's primary term and delay reclamation of the disturbed land by arguing that it would return and drill to total depth in the future. The BLM is proposing to add paragraphs (b) and (c) to remove the loophole and encourage operators to pursue diligent development of leased lands.

The proposed rule would add a new paragraph (b) to state that the approved APD expires on the date as written unless the operator has: (1) drilled the well to the approximate total depth in the approved APD; (2) is drilling the well with a rig capable of drilling the well to total depth; or (3) submits a plan, approved by the BLM, for continuously drilling the well to reach the proposed total depth in the approved APD. If the APD expiration date passes without satisfying one of these three requirements, the operator would need to submit a new APD to drill or continue drilling the well under the expired APD.

The proposed rule adds a new paragraph (c) to address outstanding surface disturbance or wellbores upon the APD's expiration. The new section states that upon expiration of the approved APD, if the operator created surface disturbance or began drilling the well under the approved APD, the operator or lessee must comply with plugging, abandonment, and reclamation requirements. The BLM proposes to add this section to ensure operators will promptly resolve any surface disturbance or wellbores upon expiration of the APD.

24. Section-by-Section Discussion for Changes to 43 CFR Subpart 3186

The proposed rule would remove the existing § 3186.2 regulations in their entirety, consistent with the changes in 43 CFR 3104.4 to remove the unit operator's bond.

VI. Overview of Modifications

The following is an overview table of the proposed significant modifications to parts 3000, 3100, 3110, 3120, 3130, 3140, 3150, 3160, 3171, and 3180:

43 CFR Part 3110—Noncompetitive Leases

• Removes this part in its entirety as required by the IRA.

VII. Procedural Matters

A. Regulatory Planning and Review (E.O. 12866, E.O. 13563)

Executive Order 12866 provides that the Office of Information and Regulatory Affairs (OIRA) within the OMB will review all significant rules. The OIRA has determined that this proposed rule is economically significant.

Executive Order 13563 reaffirms the principles of Executive Order 12866 while calling for improvements in the Nation's regulatory system to promote predictability, to reduce uncertainty, and to use the best, most innovative, and least burdensome tools for achieving regulatory ends. The Executive Order directs agencies to consider regulatory approaches that reduce burdens and maintain flexibility and freedom of choice for the public where these approaches are relevant, feasible, and consistent with regulatory objectives. Executive Order 13563 emphasizes further that regulations must be based on the best available science and that the rulemaking process must allow for public participation and an open exchange of ideas. We have developed this rule in a manner consistent with these requirements.

This proposed rule would replace the BLM's current rules governing oil and gas leasing, which are contained in 43 CFR 3100 through 3140, and revise some oil and gas operations, which are contained in 43 CFR 3160 and 3171. The BLM developed this proposed rule in a manner consistent with the requirements in Executive Order 12866 and Executive Order 13563.

The BLM reviewed the requirements of the proposed rule and determined that it would not adversely affect in a material way the economy, a sector of the economy, productivity, competition, jobs, the environment, public health or safety, or State, local, or Tribal governments or communities. For more detailed information, see the RIA prepared for this proposed rule. The RIA has been posted in the docket for the proposed rule on the Federal eRulemaking Portal: https://www.regulations.gov. In the Searchbox, enter “RIN 1004–AE80”, click the “Search” button, open the Docket Folder, and look under Supporting Documents.

B. Regulatory Flexibility Act

The Regulatory Flexibility Act (5 U.S.C. 601 et seq.) (RFA) requires that Federal agencies prepare a regulatory flexibility analysis for rules subject to the notice-and-comment rulemaking requirements under the Administrative Procedure Act (5 U.S.C. 500 et seq.), if the rule would have a significant economic impact, whether detrimental or beneficial, on a substantial number of small entities. See 5 U.S.C. 601–612. Congress enacted the RFA to ensure that government regulations do not unnecessarily or disproportionately burden small entities. Small entities include small businesses, small governmental jurisdictions, and small not-for-profit enterprises.

The BLM reviewed the SBA size standards for small businesses and the number of entities fitting those size standards as reported by the U.S. Census Bureau in the Economic Census. The number of small businesses in states where there are existing Federal oil and gas leases is estimated to be 20,975 for the Crude Petroleum Extraction and Natural Gas Extraction industries (NAICS codes 211120 and 21130, respectively). The BLM concludes that the proposed bonding requirement changes might increase challenges when securing bonds, especially for small businesses. This will increase the cost for business on Federal onshore oil and gas leases and might provide some incentives to shift leasing and operations to State or private lands. The cost of securing bonds may have a disproportionately larger impact on small businesses because it results in a larger percentage of the companies' net revenue. However, because the bonds would cost an estimated 1 to 3.5 percent of the bond value (one bonding agency reported that over 70 percent of their small-business customers paid 2 percent or less on their surety bond premiums) the annual cost to secure a bond would not be material (see https://www.insureon.com/small-business-insurance/surety-bonds/cost ).

Finally, the rule would have a distributional and positive impact on the Direct Property and Casualty Insurance Carriers Industry (NAICS 524126). Additional premiums would be paid by lessees in the oil and natural gas extraction industries to surety companies who would be providing the coverage to meet the proposed requirements. The number of small businesses in states where there are existing Federal oil and gas leases is estimated to be 476,687 in that industry.

C. Congressional Review Act

Based upon the economic analysis, this proposed rule is not a major rule under 5 U.S.C. 804(2), the Congressional Review Act. This proposed rule:

(a) Would not have an annual effect on the economy of $100 million or more.

(b) Would not cause a major increase in costs or prices for consumers, individual industries, Federal, State, or local government agencies, or geographic regions.

(c) Would not have significant adverse effects on competition, employment, investment, productivity, innovation, or the ability of U.S. based enterprises to compete with foreign based enterprises.

D. Unfunded Mandates Reform Act (UMRA)

The proposed rule would not have a significant or unique effect on State, local, or tribal governments or the private sector. The proposed rule contains no requirements that would apply to State, local, or tribal governments. The proposed rule would revise requirements that would otherwise apply to the private sector participation in a voluntary Federal program. The costs that the proposed rule would impose on the private sector are below the monetary threshold established at 2 U.S.C. 1532(a). A statement containing the information required by the Unfunded Mandates Reform Act (UMRA) (2 U.S.C. 1531 et seq.) is therefore not required for the proposed rule. This proposed rule is also not subject to the requirements of section 203 of UMRA because it contains no regulatory requirements that might significantly or uniquely affect small governments, because it contains no requirements that apply to such governments, nor does it impose obligations upon them.

E. Governmental Actions and Interference With Constitutionally Protected Property Right—Takings (Executive Order 12630)

This proposed rule would not affect a taking of private property or otherwise have taking implications under Executive Order 12630. A takings implication assessment is not required. The proposed rule would replace the BLM's current rules governing oil and gas leasing, which are contained in 43 CFR 3100 through 3140, and some oil and gas operations, which are contained in 43 CFR 3160 and 3171. Therefore, the proposed rule would impact future leases on Federal land; however, it would not impact current leases. All other terms in the regulations are not considered a taking of private property as such operations are subject to the existing lease terms which expressly require that subsequent lease activities be conducted in compliance with subsequently adopted Federal laws and regulations.

This proposed rule conforms to the terms of the existing leases and applicable statutes and, as such, the rule is not a government action capable of interfering with constitutionally protected property rights. Therefore, the BLM has determined that the rule would not cause a taking of private property or require further discussion of takings implications under Executive Order 12630.

F. Federalism (Executive Order 13132)

Under the criteria in section 1 of Executive Order 13132, this proposed rule does not have sufficient federalism implications to warrant the preparation of a federalism summary impact statement. A federalism impact statement is not required.

The proposed rule would not have a substantial direct effect on the States, on the relationship between the Federal Government and the States, or on the distribution of power and responsibilities among the levels of government. It would not apply to States or local governments or State or local governmental entities. The rule would affect the relationship between operators, lessees, and the BLM, but it does not directly impact the States. Therefore, in accordance with Executive Order 13132, the BLM has determined that this proposed rule does not have sufficient federalism implications to warrant preparation of a Federalism Assessment.

G. Civil Justice Reform (Executive Order 12988)

This proposed rule complies with the requirements of Executive Order 12988. More specifically, this proposed rule meets the criteria of section 3(a), which requires agencies to review all regulations to eliminate errors and ambiguity and to write all regulations to minimize litigation. This proposed rule also meets the criteria of section 3(b)(2), which requires agencies to write all regulations in clear language with clear legal standards.

H. Consultation and Coordination With Indian Tribal Governments (Executive Order 13175 and Departmental Policy)

The Department strives to strengthen its government-to-government relationship with Indian Tribes through a commitment to consultation with Indian Tribes and recognition of their right to self-governance and tribal sovereignty.

The BLM evaluated this proposed rule under the Department's consultation policy and under the criteria in Executive Order 13175 to identify possible effects of the rule on federally recognized Indian Tribes. Since the proposed changes to leasing only apply to Federal lands, the proposed rule will not impact the leasing of Indian minerals.

In August of 2021, the BLM sent a letter to each registered Tribe informing them of certain rulemaking efforts, including the development of this proposed rule. The letter offered Tribes the opportunity for individual government-to-government consultation regarding the proposed rule. The opportunity for tribal consultation will remain open throughout the rulemaking process.

I. Paperwork Reduction Act

The Paperwork Reduction Act (PRA) (44 U.S.C. 3501–3521) generally provides that an agency may not conduct or sponsor, and not withstanding any other provision of law a person is not required to respond to, a collection of information, unless it displays a currently valid OMB control number. Collections of information include any request or requirement that persons obtain, maintain, retain, or report information to an agency, or disclose information to a third party or to the public (44 U.S.C. 3502(3) and 5 CFR 1320.3(c)).

This proposed rule contains information-collection requirements that are subject to review by OMB under the PRA. OMB has generally approved the existing information collection requirements contained in the regulations that would be affected by this proposed rule under the following OMB Control Numbers:

• 43 CFR 3100, 3120, and Subpart 3162—OMB Control Number 1004–0185;
• 43 CFR 3106—OMB Control Number 1004–0034;
• 43 CFR part 3130—OMB Control Number 1004–0196;
• 43 CFR 3150—OMB Control Number 1004–0162; and
• 43 CFR 3160—OMB Control Number 1004–0137.

The BLM plans to transfer the information collection requirements contained in 43 CFR 3106 from OMB control number 1004–0034 to OMB Control Number 1004–0185 in order to keep similar information collections requirements together under the same OMB Control Number. Additionally, the BLM plans to transfer information collection requirements contained in 43 CFR 3160 from OMB Control Number 1004–0137 to a new OMB Control Number. The new and revised information collection requirements are discussed as follows, along with the resulting changes in public burdens.

1. Proposed Changes Impacting Information Collections Formerly Under OMB Control Number 1004–0137

The proposed rule would result in new information collection requirements that would require OMB approval under a new OMB control number (formerly 1004–0137). This proposed rule is estimated to result in 33,121 annual responses, 252,928 annual burden hours, $35,400,000 non-hour cost burdens under this new OMB Control Number.

The proposed new information collection requirements are described as follows.

43 CFR 3162.3–4—Well Abandonment. The BLM is proposing to modify paragraph (c) to include that no well may be temporarily abandoned unless the operator provides adequate and detailed justifications, verifies the mechanical integrity of the wells, and isolates the completed interval(s). The BLM proposes to add a new paragraph (d) outlining new requirements for operators of shut-in wells. Paragraph (d)(1) provides for notification of the well's shut-in status and shut-in date within 90 days of shut in. Paragraph (d)(2) provides for the verification of the mechanical integrity of the well and confirmation that the well remains capable of producing in paying quantities within 3 years. When a well remains in a shut-in status by the fourth year, as outlined in paragraph (d)(3), the operator must either: (i) permanently abandon the well; (ii) resume production; or (iii) provide a detailed plan and timeline for the beneficial use for the well. The BLM may grant additional delays provided the operator submits information that confirms the use and is making progress on returning the well to a beneficial use. The new information collection requirements would include:

• Justification for Temporary Well Abandonment—43 CFR 3162.3–4(c);
• Abandon Well Shut-in Status—43 CFR 3162.3–4(d);
• Verification of Mechanical Integrity—43 CFR 3162.3–4(d)(2); and
• Plan and Timeline for Future Beneficial Use—43 CFR 3162.3–4(d)(3)(iii).

The BLM believes these new requirements with yearly interval checks will help operators stay on top of shut-in wells, thus preventing them from becoming orphaned in the future. The addition of these information collection requirements would result in an addition of 5,000 annual responses, 44,000 annual burden hours.

Currently, there are 301,663 annual responses, 1,835,888 annual burden hours, and $31,080,000 annual non-hour cost burdens inventoried under the OMB Control Number 1004–0137. This rule will create a new OMB Control Number and removes 28,121 annual responses, 208,298 annual burden hours, and $31,080,000 annual non-hour cost burdens inventoried under OMB Control Number 1004–0137 into this OMB Control Number.

In addition, there is an adjustment of $4.3 million in annual non-hour cost burdens (from $31 million to 35.4 million). This adjustment results from the annual inflation adjustment of filing fees and do not result from the proposed rule. The resulting new estimated total burdens for this new OMB Control Number are provided as follows.

Title of Collection: Onshore Oil and Gas Operations and Production (43 CFR parts 3160 and 3170).

OMB Control Number: 1004–NEW.

Form Numbers: BLM Form 3160–003; BLM Form 3160–004; and BLM Form 3160–005 (these forms will not change).

Type of Review: Revision of a currently approved collection of information.

Respondents/Affected Public: Oil and gas operators on public lands and some Indian lands.

Total Estimated Number of Annual Respondents: 7,500.

Total Estimated Number of Annual Responses: 33,121.

Estimated Completion Time per Response: Varies from 4 to 32 hours, depending on activity.

Total Estimated Number of Annual Burden Hours: 252,928.

Respondent's Obligation: Required to obtain or retain a benefit.

Frequency of Collection: On occasion; One-time; and Monthly.

Annual Burden Cost: $35,400,000.

2. Proposed Changes Impacting OMB Control Number 1004–0162

Currently, there are 68 annual responses, 26 annual burden hours, and $25 annual non-hour cost burdens inventoried under OMB Control Number 1004–0162. It is not anticipated that the proposed rule will change the results to the annual responses, annual burden hours, or non-hour cost burdens under this OMB Control Number. The proposed revised information collection requirement is described as follows.

43 CFR 3151.3—Collection and submission of data. The proposed rule would add a new requirement for the permittee to provide the BLM with all data and information obtained in carrying out the exploration plan, matching the requirement for geophysical exploration permits in Alaska. This does not change the existing burden for what applicants need to submit to the BLM for acquiring a geophysical exploration permit.

Title of Collection: Onshore Geophysical Exploration (43 CFR part 3150 and 36 CFR parts 228 and 251).

OMB Control Number: 1004–0162.

Form Number: BLM 3150–4/FS 2800–16; BLM 3150–5/FS 2816a (these forms will not change).

Type of Review: Revision of a currently approved collection of information.

Respondents/Affected Public: The respondents for this collection of information are businesses that seek to conduct geophysical exploration on Federal lands.

Respondent's Obligation: Required to Obtain or Retain a Benefit.

Frequency of Collection: On occasion.

Estimated Completion Time per Response: Varies from 20 minutes to 1 hour, depending on activity.

Number of Respondents: 68.

Annual Responses: 68.

Annual Burden Hours: 26.

Annual Burden Cost: $1,150.

3. Proposed Changes Impacting OMB Control Number 1004–0185

Currently, there are 9,132 annual responses, 37,695 annual burden hours, and $751,415 annual non-hour cost burdens inventoried under OMB Control Number 1004–0185. This proposed rule is estimated to result in 16,340 annual responses, 29,410 annual burden hours, $1,793,159, non-hour cost burdens under this OMB Control Number. The proposed rule would result in new, revised, and removed information collection requirements. Additionally, as discussed earlier, the BLM will also be transferring certain information collection requirements, along with the associated burdens from OMB Control Number 1004–0034 to OMB Control Number 1004–0185. These proposed changes are discussed as follows.

Revised Information Collection Requirements

43 CFR 3100.31(b)—Option Enforceability. The proposed rule revises this requirement to clarify that a statement of the number of acres and the type and percentage of interest to be conveyed and retained by the parties to the option must be submitted for an option or renewal to be enforceable. This does not change the burden requirement. The existing regulation already states the interest to be conveyed and retained in exercise of the option. The BLM needs to understand if the type of interest is referring to record title or operating rights and the percentage to be conveyed and retained by the option holder.

43 CFR 3105.21—Where to File Communitization Agreements. The proposed rule removes the triplicate filing requirement. The proposed rule adds a new paragraph (b) to this section to require that all applications to form a CA be filed with a statement as to whether the proposed CA deviates from the BLM's current model CA form, and a certification that the applicant received the required signatures. Further, all applications to form a CA shall include an Exhibit A displaying a map of the agreement and the separate agreement tracts and all applications to form a CA shall include an Exhibit B displaying the separate tracts and ownership. The new paragraph (c) states that all applications to form a CA should be submitted at least 90 calendar days prior to first production to ensure correct reporting to the ONRR. These requirements codify existing policy requirements and does not change the existing burden for what applicants to submit to the BLM. The information is needed to understand all the parties that share in the production of a well due to State spacing orders.

43 CFR 3105.31—Where to file Operating, Drilling or Development Contracts. The proposed rule would remove the requirement for five copies of an operating, drilling or development contract to be submitted when these contracts are submitted to the BLM for approval. This reduces the burden to respondents.

43 CFR 3105.40—Subsurface storage application (formerly 3105.5). The proposed rule would designate the existing 43 CFR 3105.5 for gas storage agreements to the proposed numbering 43 CFR 3105.40. This redesignation would be due to the elimination of the section on the combination for joint operations or for transportation of oil. The proposed rule would update paragraph (a) to include designation of successor operators for gas storage agreements among the applications to be filed in the proper BLM office. The proposed rule would update paragraph (b) to remove the requirement for five copies of a gas storage agreements to be submitted when these are filed with the BLM. A new paragraph (c) would require that all applications for a gas storage agreement or a designation of a successor operator must include the new processing fee found in the fee schedule in 43 CFR 3000.120. The new processing fee is intended to reimburse the BLM for processing the applications.

43 CFR 3105.50—Consolidation of Leases (formerly 3105.6). Leases may be consolidated upon written request of the lessee filed with the proper BLM identify each lease involved by serial number and shall explain the factors that justify the consolidation and requires that each request for a consolidation of leases the processing fee found in the fee schedule in 43 CFR 3000.120. The proposed rule splits the single paragraph under this section into several paragraphs for clarity, however these are not new requirements and do not change the existing burden.

43 CFR 3106.81—Heirs and devisees. The proposed updates this information collection requirement to state that the lease interest will be transferred to the heirs, devisees, executor or administrator of the estate, as appropriate, upon the filing of a court order, death certificate, or other legal document demonstrating that transferee is to be recognized as the successor of the deceased. These requirements codify existing policy requirements and does not change the existing burden for what applicants currently submit to the BLM to show proof on how the lease interest transferred to another party.

43 CFR 3106.82—Change of name. The current regulation requires a notice of the name change to be accompanied by a list of the serial numbers of the leases affected by the name change. This requirement is removed as it is outdated and unenforceable. This lessens the burden to respondents. In practice, the BLM generates a report of the leases affected by the name change and returns that list to the lessee with a notice that recognizes the name change that occurred through operation of law. This section is updated to require that, for a corporate name change, the request should include the Secretary of State's Certificate of Name Change along with the Articles of Incorporation, or Amendment, if available. This is consistent with the BLM's current approach for processing these types of documents. These requirements codify existing policy requirements and do not change the existing burden for what applicants currently submit to the BLM to show proof on how the lease interest transferred to another party.

43 CFR 3106.83—Corporate mergers and dissolution of corporations, partnerships and trust. The proposed rule updates the title of this section from “Corporate merger” to “Corporate mergers and dissolution of corporations, partnerships and trust.” The goal of the renaming of this section is to incorporate these other types of transfers that have the same process. The current regulation requires a notification of merger to be accompanied by a list of the serial numbers of the leases affected by the merger. This requirement is eliminated as it is outdated and unenforceable. This lessens the burden to respondents. In practice, the BLM does not rely on a list of leases provided by a lessee and instead generates its own report of the leases affected by the merger. The BLM returns that list to the lessee with a notice that recognizes the merger that occurred through operation of State law. This section is updated to require that, for a merger, the request should include the Secretary of State's Certificate of Merger along with the Articles of Incorporation, or Amendment, if available. This is consistent with the BLM's current approach for processing these types of documents. These requirements codify existing policy requirements and do not change the existing burden for what applicants currently submit to the BLM to show proof on how the lease interest transferred to another party.

43 CFR 3108.23—Reinstatement at higher rental and royalty rates: Class II reinstatements. The proposed rule would eliminate the existing paragraph (b)(1) in its entirety. This provision addresses the timeliness of Class II reinstatement petitions for leases that terminated on or before August 8, 2005, and is no longer applicable. This does not change an existing burden since a petition to reinstate a lease that terminated on or before August 8, 2005, would have already been received by an applicant.

43 CFR 3109.12—Application. The proposed rule also adds a new requirement that the applicant must include a map of the applicable lands which will support the bidding process related to the lease or compensatory royalty agreement. These requirements codify existing policy requirements and does not change the existing burden for what applicants to submit to the BLM.

New Information Collection Requirements

43 CFR 3106.84—Sheriff's sale/deed. The proposed rule adds a new section under other types of transfers to include sheriff's sales. The BLM accepts these types of transfers to recognize lease interests transferred to other parties through foreclosure actions. The proposed rule states that where a notice of sale of the leasehold interest is published pursuant to State law applicable to the execution of sales of real property, the purchaser shall submit a copy of the Sheriff's Certificate of Sale after any redemption period has passed to the proper BLM office. Additional paragraphs under this new section include a filing fee requirement, a qualification statement, and bonding requirements. These requirements are consistent with the BLM's current approach for processing these types of documents. These documents are already submitted and recognized by the BLM when changes in ownership of interests in Federal oil and gas leases occur without any intention by the holder of interest to assign or transfer interest. The addition of this information collection would result in an addition of 1 annual response, 1 annual burden hour, and $55.80 annual non-hour cost burdens.

43 CFR 3120.43—Expression of Interest. The proposed rule adds a new section titled “Expression of Interest” to codify the current process of receiving EOIs for competitive leasing to the BLM's online leasing system. An expression of interest is a description of lands that an applicant seeks to include in a competitive auction. The expression must provide a description of the lands identified by legal land description and identify the U.S. mineral ownership percentage. The addition of this information collection would result in an addition of 395,864 annual responses (calculated by acreage received), 3,958,640 annual burden hours (to process the acreage received), and $220,892,112 annual non-hour cost burdens.

Removed Information Collection Requirements

43 CFR 3101.26—Ad-Hoc Acreage Statement. At any time, the BLM may require a lessee or operator to file a statement showing as of the specified date, the serial number and the date of each lease in which he/she has any interest, in the particular State, setting forth the acreage covered thereby. The BLM uses the information to determine whether or not a lessee is in compliance with the law with respect to statutory acreage limitations. This revision results in the reduction of 1 response and 1 burden hour, annually.

43 CFR 3105.4—Combination for joint operations or for transportation of oil. The proposed rule eliminates the section on the combination for joint operations or for transportation of oil. These provisions are not used by the BLM or operators and are outdated. This revision results in the reduction of 1 response and 1 burden hour, annually.

43 CFR 3107.8—Renewal leases. The proposed rule eliminates the provisions on renewal leases in their entirety because they are outdated. Renewal leases that had an expiration date after November 15, 1990, were eligible for one last renewal under the provisions of the November 15, 1990, Act, i.e., for 10 years, and for so long thereafter as oil and gas is produced in paying quantities. If a lease was renewed after the 1990 amendment and was not producing oil or gas at the end of its 10-year renewal term, the lease expired with no further option for renewal. The removal of this information collection would result in a reduction 1 annual response, 1 annual burden hour, and $475 annual non-hour cost burdens.

D. Class III reinstatement petition (43 CFR 3108.2–4).

The requirement would be removed from the proposed rule resulting in a reduction of one annual response and one burden hour as well as $651 in non-hour cost burden.

Information Collection Requirements Transferred From OMB Control Number 1004–0034.

The following two information collection will be moved into OMB Control Number 1004–0185 to keep information collection requirements in Subpart 3106 under the same OMB Control Number:

1. 43 CFR 3106.41—Transfers of record title and of operating rights (subleases) and 3106.42, Transfers of other interests, including royalty interests and production payments. This transfer would result in 3,852 annual responses, 1,926 annual burden hours, and $404,460 non-hours cost burdens being added to this OMB Control Number.

2. 43 CFR 3106.43—Mass transfers. This transfer would result in 4,944 annual responses, 2,472 annual burden hours, and $519,120 non-hours cost burdens being added to this OMB Control Number.

The resulting new estimated total burdens for OMB Control Number 1004–0185 are provided as follows.

Title of Collection: Onshore Oil and Gas Leasing, and Drainage Protection (43 CFR parts 3100, 3120, and 3150, and Subpart 3162).

OMB Control Number: 1004–0185.

Form Number: None.

Type of Review: Revision of a currently approved collection of information.

Respondents/Affected Public: Holders of onshore oil and gas lease and public lands and Indian lands (except on the Osage Reservation), operators of such leases, and holders of operating rights on such leases.

Respondent's Obligation: Required to Obtain or Retain a Benefit.

Frequency of Collection: Varies from 1 hour to 24 hours per response, depending on activity.

Number of Respondents: 16,339.

Annual Responses: 16,340.

Annual Burden Hours: 29,410.

Annual Burden Cost: $1,793,159.

4. Proposed Changes Impacting OMB Control Number 1004–0196

Currently, there are there are 21 annual responses and 220 annual burden hours associated with this OMB control number. There are also no non-hours cost burden currently associated with this OMB control number. The proposed rule is not projected to result in any new annual responses The additional requirements proposed in 43 CFR 3170.80(b) include description of the anticipated PA(s) size and define the proposed PAs in the unit designation agreements required by 43 CFR 3137.21, and 3137.23 is not projected to result in additional burden for that information collection.

43 CFR 3000.12 would introduce new filing fees for the following information collections, resulting in a new non-hour burden cost of $1,320:

• Statement of change of unit operator (43 CFR 3137.61); and
• Application for storage agreement (43 CFR 3138.11). Additionally, 43 CFR 3137.86, New information demonstrating that the participating area should be larger or smaller than previously determined, contains the following three information collection requirements for which the burden has not been formerly captured in this OMB control number:
• Information demonstrating that a participating area should be larger than previously determined (43 CFR 3137.86(a)(1));
• Application to enlarge participating area outside of existing boundaries (43 CFR 3137.86(a)(2)); and
• Statement for additional committed tract or tracts are added to the unit under paragraph (a)(2) (43 CFR 3137.86(a)(3)).

The resulting new estimated total burdens for OMB Control Number 1004–0196 are provided as follows.

Title of Collection: Oil and Gas Leasing: National Petroleum Reserve—Alaska (43 CFR part 3130).

OMB Control Number: 1004–0196.

Form Number: None.

Type of Review: Revision of a currently approved collection of information.

Respondents/Affected Public: Participants within the oil and gas leasing program within the National Petroleum Reserve-Alaska.

Respondent's Obligation: Required to Obtain or Retain a Benefit.

Frequency of Collection: On occasion.

Estimated Completion Time per Response: Varies from 15 minutes to 80 hours, depending on activity.

Number of Respondents: 24.

Annual Responses: 24.

Annual Burden Hours: 223.

Annual Burden Cost: $1,320.

In summary, the net burden changes that would result from the new, revised, and removed information collection requirements as contained in the proposed rule are as follows:

If you want to comment on the information-collection requirements of this proposed rule, please send your comments and suggestions on this information-collection by the date indicated in the DATES and ADDRESSES sections as previously described

J. National Environmental Policy Act

A detailed environmental analysis under NEPA is not required, because the proposed rule is covered by a categorical exclusion (see 43 CFR 46.205). This proposed rule meets the criteria set forth at 43 CFR 46.210(i) for a Departmental categorical exclusion in that this proposed rule is “of an administrative, financial, legal, technical, or procedural nature.” We have also determined that the proposed rule does not involve any of the extraordinary circumstances listed in 43 CFR 46.215 that would require further analysis under NEPA.

K. Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use (Executive Order 13211)

Under Executive Order 13211, agencies are required to prepare and submit to OMB a Statement of Energy Effects for significant energy actions. This statement is to include a detailed statement of “any adverse effects on energy supply, distribution, or use (including a shortfall in supply, price increases, and increase use of foreign supplies)” for the action and reasonable alternatives and their effects.

Section 4(b) of Executive Order 13211 defines a “significant energy action” as “any action by an agency (normally published in the Federal Register ) that promulgates or is expected to lead to the promulgation of a final rule or regulation, including notices of inquiry, advance notices of proposed rulemaking, and notices of proposed rulemaking: (1)(i) that is a significant regulatory action under Executive Order 12866 or any successor order, and (ii) is likely to have a significant adverse effect on the supply, distribution, or use of energy; or (2) that is designated by OIRA as a significant energy action.”

The BLM believes that the rule may affect the location chosen for future oil or gas development but will have little impact on an entity's decision to invest in energy development, the size of that development, or the production from that development. As a result of this rule, an entity holding existing nonproducing leases may choose to shift more future development to these existing leases or to develop non-Federal acreage instead of securing new Federal leases, and some entities may be relatively less likely to choose a new Federal lease to a comparable non-Federal lease. Also, any incremental changes in oil or gas production estimated to result from the rule's enactment would constitute a small fraction of total U.S. gas production, and any potential and temporary deferred production of oil would likewise constitute a small fraction of total U.S. oil production. For these reasons, we do not expect that the proposed rule would significantly impact the supply, distribution, or use of energy. As such, the rulemaking is not a “significant energy action” as defined in Executive Order 13211.

L. Clarity of This Regulation (Executive Orders 12866, 12988, and 13563)

We are required by Executive Orders 12866 (section 1(b)(12)), 12988 (section 3(b)(1)(B)), and 13563 (section 1(a)), and by the Presidential Memorandum of June 1, 1988, to write all rules in plain language. This means that each rule must:

(a) Be logically organized;

(b) Use the active voice to address readers directly;

(c) Use common, everyday words and clear language rather than jargon;

(d) Be divided into short sections and sentences; and

(e) Use lists and tables wherever possible.

If you feel that we have not met these requirements, send us comments by one of the methods listed in the ADDRESSES section. To better help the BLM revise the proposed rule, your comments should be as specific as possible. For example, you should tell us the numbers of the sections or paragraphs that you find unclear, which sections or sentences are too long, the sections where you feel lists or tables would be useful, etc.

Authors

The principal authors of this final rule include: Peter Cowan, Senior Mineral Leasing Specialist in BLM Headquarters; Jennifer Spencer, Mineral Leasing Specialist in BLM Headquarters; William Lambert, Petroleum Engineer in BLM Headquarters; Christopher Rhymes, former Attorney Advisor in DOI Office of the Solicitor. Technical support provided by: Scott Rickard, Economist in BLM Headquarters; Holly Elliott, Planning and Environmental Specialist in BLM Wind River Bighorn Basin District; Erik Vernon, Air Resources Program Lead in BLM Utah State Office; Bret Anderson, National Air Resources Program Lead in BLM Headquarters; and James Tichenor, Technical Advisor in BLM Headquarters. Assisted by: Duane Spencer, Deputy State Director of Minerals and Land in BLM Wyoming State Office; JulieAnn Serrano, Supervisory Land Law Examiner in BLM New Mexico State Office; Rebecca Baca, former Supervisory Land Law Examiner in BLM Colorado State Office; and Darrin King, Senior Regulatory Analysts in BLM Headquarters.

List of Subjects

43 CFR Part 3000

• Public lands-mineral resources
• Reporting and recordkeeping requirements

43 CFR Part 3100

• Government contracts
• Mineral royalties
• Oil and gas reserves
• Public lands-mineral resources
• Reporting and recordkeeping requirements
• Surety bonds

43 CFR Part 3110

• Government contracts
• Oil and gas exploration
• Public lands-mineral resources
• Reporting and recordkeeping requirements

43 CFR Part 3120

• Government contracts
• Oil and gas exploration
• Public lands-mineral resources
• Reporting and recordkeeping requirements

43 CFR Part 3130

• Alaska
• Government contracts
• Mineral royalties
• Oil and gas exploration
• Oil and gas reserves
• Public lands-mineral resources
• Reporting and recordkeeping requirements
• Surety bonds

43 CFR Part 3140

• Government contracts
• Hydrocarbons
• Mineral royalties
• Oil and gas exploration
• Public lands-mineral resources
• Reporting and recordkeeping requirements

43 CFR Part 3150

• Administrative practice and procedure
• Alaska
• Oil and gas exploration
• Public lands-mineral resources
• Reporting and recordkeeping requirements
• Surety bonds

43 CFR Part 3160

• Administrative practice and procedure
• Government contracts
• Indians-lands
• Mineral royalties
• Oil and gas exploration
• Penalties
• Public lands-mineral resources
• Reporting and recordkeeping requirements

43 CFR Part 3170

• Administrative practice and procedure
• Flaring
• Immediate assessments
• Indians-lands
• Mineral royalties
• Oil and gas exploration
• Oil and gas measurement
• Public lands—mineral resources
• Reporting and record keeping requirements
• Royalty-free use
• Venting

43 CFR Part 3180

• Government contracts
• Mineral royalties
• Oil and gas exploration
• Public lands-mineral resources
• Reporting and recordkeeping requirements

43 CFR Chapter II

For the reasons set out in the preamble, the Bureau of Land Management proposes to amend 43 CFR parts 3000, 3100, 3110, 3120, 3130, 3140, 3150, 3160, 3170, and 3180 as follows:

1. Revise part 3000 to read as follows:

PART 3000—MINERALS MANAGEMENT: GENERAL

Authority: 16 U.S.C. 3101 et seq.; 30 U.S.C. 181 et seq., 301–306, 351–359, and 601 et seq.; 31 U.S.C. 9701; 40 U.S.C. 471 et seq.; 42 U.S.C. 6508; 43 U.S.C. 1701 et seq.; and Pub. L. 97–35, 95 Stat. 357.

2. Revise part 3100 to read as follows:

PART 3100—OIL AND GAS LEASING

Authority: 25 U.S.C. 396d and 2107; 30 U.S.C. 189, 306, 359, and 1751; 43 U.S.C. 1732(b), 1733, and 1740; and 42 U.S.C. 15801.

Subpart 3100—Onshore Oil and Gas Leasing: General

Subpart 3101—Issuance of Leases

Lease Terms and Conditions

Subpart 3102—Qualifications of Lessees

Subpart 3103—Fees, Rentals and Royalty Payments

Subpart 3104—Bonds

Subpart 3105—Cooperative Conservation Provisions

Subpart 3106—Transfers by Assignment, Sublease, or Otherwise

Subpart 3107—Continuation and Extension

Subpart 3108—Relinquishment, Termination, Cancellation

Subpart 3109—Leasing Under Special Acts

Rights-of-Way

PART 3110 [REMOVED]

3. Under the authority of 30 U.S.C. 189, part 3110 is removed.

4. Revise part 3120 to read as follows:

PART 3120—COMPETITIVE LEASES

Authority: 16 U.S.C. 3101 et seq.; 30 U.S.C. 181 et seq. and 351–359; 40 U.S.C. 471 et seq.; 43 U.S.C. 1701 et seq.; Pub. L. 113–291, 128 Stat. 3762; and the Attorney General's Opinion of April 2, 1941 (40 Op. Atty. Gen. 41).

Subpart 3120—Competitive Leases

General

PART 3130—OIL AND GAS LEASING: NATIONAL PETROLEUM RESERVE, ALASKA

5. The authority citation for part 3130 continues to read as follows:

Authority: 42 U.S.C. 6508, 43 U.S.C. 1733 and 1740.

6. Revise § 3137.23 to read as follows:

7. Revise § 3137.61 to read as follows:

8. Revise § 3138.11 to read as follows:

9. Revise part 3140 to read as follows:

PART 3140—LEASING IN SPECIAL TAR SAND AREAS

Authority: 30 U.S.C. 181 et seq.; 30 U.S.C. 351–359; 43 U.S.C. 1701 et seq.; Pub. L. 97–78, 95 Stat. 1070; 42 U.S.C. 15801, unless otherwise noted.

Subpart 3140—Conversion of Existing Oil and Gas Leases and Valid Claims Based on Mineral Locations

Subpart 3141—Leasing in Special Tar Sand Areas

Subpart 3142—Paying Quantities/Diligent Development for Combined Hydrocarbon and Tar Sand Leases

PART 3150—ONSHORE OIL AND GAS GEOPHYSICAL EXPLORATION

10. The authority citation for part 3150 continues to read as follows:

Authority: 16 U.S.C. 3150(b) and 668dd; 30 U.S.C. 189 and 359; 42 U.S.C. 6508; 43 U.S.C. 1201, 1732(b), 1733, 1734, 1740.

11. Revise subpart 3151 to read as follows:

Subpart 3151—Exploration Outside of Alaska

PART 3160—ONSHORE OIL AND GAS OPERATIONS

12. The authority citation for part 3160 continues to read as follows:

Authority: 25 U.S.C. 396d and 2107; 30 U.S.C. 189, 306, 359, and 1751; 43 U.S.C. 1732(b), 1733, 1740; and Sec. 107, Pub. L. 114–74, 129 Stat. 599, unless otherwise noted.

13. Revise § 3160.0–5 to read as follows:

14. Revise § 3162.3–4 to read as follows:

15. Revise § 3165.1 to read as follows:

PART 3170—ONSHORE OIL AND GAS PRODUCTION

16. The authority citation for part 3170 continues to read as follows:

Authority: 25 U.S.C. 396d and 2107; 30 U.S.C. 189, 306, 359, and 1751; and 43 U.S.C. 1732(b), 1733, and 1740.

17. Revise § 3171.6 to read as follows:

18. Revise § 3171.14 to read as follows:

PART 3180—ONSHORE OIL AND GAS UNIT AGREEMENTS: UNPROVEN AREAS

19. The authority citation for part 3180 continues to read as follows:

Authority: 30 U.S.C. 189.

20. Remove § 3186.2.