BIA Indian Land Leasing

Approximately 55 million acres of land are held in federal trust for American Indian tribes and individual Indians — land that cannot be sold without federal approval but that owners and tribes may lease for farming, housing, business, or energy development. The Bureau of Indian Affairs (BIA), within the Department of the Interior, administers leasing of this land under 25 CFR Part 162, which governs agricultural leases (Subpart B), residential leases (Subpart C), business leases (Subpart D), and wind and solar energy development leases (Subpart E). The regulation balances Indian landowner control with federal trust responsibility: most leases require landowner consent, but BIA approval is required for leases to be enforceable, and BIA holds authority to suspend or cancel leases when the trust relationship demands it. Fractionated ownership — a single parcel divided among dozens or hundreds of heirs over generations — creates consent challenges that the regulations address through majority-interest consent rules for tracts with many owners.

Current Rule (2026)

What This Rule Does

25 CFR Part 162 sets the legal framework for leasing Indian trust and restricted land — land whose title is held in trust by the federal government for an Indian tribe or individual, or land held by an Indian with restrictions against alienation without federal approval. Part 162's core purpose (§ 162.001) is to support tribal economic self-sufficiency and self-determination, promote Indian ownership and control of Indian lands, and support tribal agricultural and business development.

Scope (§ 162.004): Part 162 applies to leases of trust or restricted land — land held in trust by the United States for an Indian tribe or individual Indian, or land held by an Indian or Indian tribe subject to a restriction against alienation imposed by the United States. It does not apply to land that has been taken out of trust or to fee land owned by tribal members without restrictions. The regulation covers the full lifecycle of a lease: consent, approval, rent and payment terms, BIA oversight, compliance, and cancellation.

When a Lease is Required (§ 162.005): A lease is required whenever non-owners are authorized to possess or use trust or restricted land for any purpose other than certain exempt activities (religious, educational, recreational, or subsistence use by the Indian owner). Without a BIA-approved lease, any agreement purporting to authorize another party to use trust land is unenforceable.

Key Provisions

§ 162.001 — Purpose: promote Indian self-determination and self-sufficiency; support tribal agricultural and economic development; protect Indian landowners through trust oversight

§ 162.004 — Scope: applies to trust land held for tribes or individual Indians; restricted-fee land; does not apply to fee land without federal restrictions

§ 162.005 — When lease required: required whenever non-owner possesses or uses trust/restricted land; religious, educational, recreational, and subsistence uses by Indian owners are exempt

§ 162.006 — Statutory authority: 25 U.S.C. § 380 (general leasing), § 415(a) (25-year leases up to 99 years with tribal approval), § 4211 (American Indian Agricultural Resource Management Act)

§ 162.010 — How to obtain a lease: landowner(s) initiate leasing process; work with tribe or BIA agency; BIA reviews for legal compliance and trust obligations; BIA approval required for lease to be effective

§ 162.012 — Consent requirements for fractionated tracts: when a tract has many co-owners (common after generations of inheritance), a lease requires consent of the owners of the majority interest; where a tribe owns an interest, tribal consent is required; BIA may also consent on behalf of heirs who cannot be located

§ 162.013 — Tribal authority: tribes with approved tribal land leasing regulations may negotiate and approve certain leases without BIA involvement; BIA retains approval authority for leases that do not meet tribal regulatory requirements

§ 162.022 — Holdover: a tenant who remains in possession after lease expiration without a new lease or extension is a holdover tenant; BIA may assess trespass damages

§ 162.029 — BIA's role in lease compliance: BIA monitors compliance, investigates complaints, and may issue notices of noncompliance; lease cancellation authority if lessee fails to cure default

Subpart Structure

Subpart B — Agricultural Leases (67 sections): covers farming and grazing leases. Key provisions include minimum rental rate requirements based on comparable land values, preference rights for Indian lessees on renewals, minimum 3-year terms for dry farming, and grazing lease provisions including livestock capacity determinations. BIA must verify that rent equals or exceeds fair market value unless the tribe waives this requirement.

Subpart C — Residential Leases (59 sections): covers housing, both for individual Indians and for tribal housing programs. Residential leases may be long-term (25–75 years) when used as collateral for home financing — an important provision that enables mortgage lending on trust land. The residential lease framework works with the Native American Housing Assistance and Self-Determination Act (NAHASDA) and Section 184 Indian home loan guarantee program.

Subpart D — Business Leases (62 sections): covers commercial, industrial, and other non-agricultural, non-residential uses. Business leases may run up to 25 years (renewable) without special statutory authorization, or longer (up to 99 years) with tribal approval under § 415(a). Rent must equal fair market value unless waived by the tribe; required bonding and insurance provisions protect Indian landowners against default.

Subpart E — Wind and Solar Energy Development Leases (90 sections — the largest subpart): covers leasing for wind turbine and solar generation facilities. This is the most complex subpart, reflecting the need to balance long lease terms (projects require financing over 25-50 years), revenue sharing, and protection of Indian landowners. Key provisions include: feasibility study requirements before lease execution; right-of-way coordination when transmission lines cross multiple parcels; community benefit provisions; and detailed bonding requirements to ensure decommissioning and land restoration when projects end.

Subpart F — Special Reservations and Restricted Fee Land (4 sections): covers leasing rules that apply specifically to certain reservations with unique statutory frameworks — including Osage, Five Civilized Tribes in Oklahoma, and other reservations with special statutory treatment.

25 CFR Part 213 — Leasing of Restricted Lands of Members of Five Civilized Tribes, Oklahoma, for Mining:

Part 213 is a specialized lease regulatory framework for the restricted fee lands of members of the Five Civilized Tribes — the Cherokee, Chickasaw, Choctaw, Creek (Muscogee), and Seminole Nations of Oklahoma. These lands are "restricted fee" (privately owned by tribal members but subject to federal restrictions on alienation), not "trust" land in the conventional sense; the Five Civilized Tribes hold their landholdings in a distinct legal status arising from the Curtis Act of 1898 and the Dawes Allotment rolls. Part 213 governs specifically mining leases on these restricted lands, authorized by 25 U.S.C. § 356:

• § 213.1 — Definitions: "Area Director" refers to the officer in charge of the Five Civilized Tribes Agency of BIA (headquartered in Muskogee, Oklahoma); references to the "Secretary" mean the Secretary of the Interior or authorized representatives; all approvals under Part 213 flow through the Five Civilized Tribes Agency, not through regular BIA regional offices

• § 213.2 — Applications: mining lease applications must be submitted to the Area Director; applications must describe the land, the proposed mineral development, and the applicant's qualifications; the Area Director determines whether to recommend approval to the Secretary

• § 213.10 — Signature requirements: a tribal member lessor who cannot write their name must sign all official papers with a mark (traditionally an X) witnessed by two adult witnesses — a provision dating to the era when many Dawes allottees were not literate in English; the witnessed mark is legally equivalent to a signature

• § 213.11–213.12 — Minor lessors: if the lessor is a minor, BIA requires certified copies of guardianship letters and court orders authorizing the lease; leases by guardians on behalf of minors are subject to court approval, protecting underage landowners from improvident leasing

• § 213.13 — Inherited undivided lands: mining leases on undivided inherited lands (land that passed to multiple heirs through intestate succession without partitioning) generally may not be approved without all heirs' consent — "except to prevent loss or waste"; this provision addresses the fractionation problem specific to the Five Civilized Tribes' restricted fee landholdings, where successive inheritance has divided many parcels among dozens or hundreds of co-owners

• § 213.15 — Bonds: lessees must post a bond (BIA Form 5-154b) with the Area Director before any mining lease takes effect; bond amounts are set to cover potential damages from mining operations; assignees of existing leases must also post their own bonds

• § 213.18 — Royalty payments: all rents and royalties under Part 213 are paid to the Area Director, who credits them to the individual Indian's money (IIM) account; BIA serves as the financial trustee — individual tribal members receive their royalty income through their IIM accounts rather than directly from lessees

• § 213.17 — Government purchase right: in times of war or public emergency, the government reserves the right to purchase at reasonable market prices any minerals produced under a Part 213 lease — a wartime minerals security provision carried over from World War II-era regulations

  Part 213's distinct legal framework reflects the historical complexity of Five Civilized Tribes land tenure. Unlike most Indian tribes whose lands are held in federal trust (title in the United States), Five Civilized Tribes restricted fee lands are individually owned by tribal members with federal restrictions on sale and encumbrance — a product of the allotment era's partial dismantlement of tribal communal land systems. Mining leases on these lands require federal approval under § 356 because the restriction on alienation means landowners cannot freely encumber their land; BIA's approval role is part of the federal protection against improvident alienation, not a trust ownership relationship. Oklahoma's significant oil and gas reserves overlap substantially with Five Civilized Tribes restricted fee lands, making Part 213 directly relevant to petroleum, natural gas, and coal mining operations in eastern Oklahoma.

25 CFR Part 140 — Licensed Indian Traders: One of the oldest continuing federal regulatory regimes, the Indian trader licensing system requires BIA authorization for any non-tribal-member who wants to engage in commerce with Indians on a reservation. The licensing authority derives from 25 U.S.C. § 264, part of the Indian Trade and Intercourse Act statutory framework dating to the late 18th century, and has been upheld by the Supreme Court as a core element of federal preemption of state commercial law within Indian country (Warren Trading Post Co. v. Arizona Tax Commission, 380 U.S. 685 (1965)).

• § 140.1 — Sole BIA authority: the Commissioner of Indian Affairs has the "sole power and authority" to appoint traders to Indian tribes; any person wishing to trade on a reservation must satisfy the Commissioner that they are "a proper person" to engage in such trade — a character and fitness standard with no fixed criteria, giving BIA broad discretion in granting or withholding licenses

• § 140.11 — License requirements and term: a trader's license will not issue unless the applicant holds a legal right to use the land where the business will be conducted (a lease or permit on restricted Indian land); the license period corresponds to the land use right, with a maximum of 25 years; licenses are personal and do not run with the land

• § 140.12 — Renewal: renewal applications must be submitted to the Commissioner through the local superintendent at least 30 days before license expiration; the superintendent reports on the trader's record and fitness for renewal

• § 140.13–140.14 — Enforcement: the superintendent may direct closure of any unlicensed store; trade is limited to the premises specified in the license; branch stores require separate licenses and bonds; the bonded principal must reside habitually on the reservation

• § 140.15 — No subletting: licensed traders may not lease, sublet, or sell their business premises without the Commissioner's approval; the trader's license confers no right to use reservation land for livestock grazing or other non-trading purposes

• § 140.16 — Prohibited trade: traders may not buy, trade for, or possess any goods purchased or furnished by the government for Indian welfare (annuities, ration goods); government-purchased livestock owned by Indians may not be purchased by non-tribal-member traders without the tribal agent's written consent

• § 140.18 — Liquor prohibition: sale or introduction of alcoholic beverages on an Indian reservation is prohibited, consistent with federal liquor laws applicable to Indian country under 18 U.S.C. §§ 1154–1156

  In practice, the Indian trader licensing requirement applies today to non-Indian retail businesses, trading posts, and service operations located on reservation land — particularly in the Southwest where reservation-based retail has significant economic scale. Federal preemption under the trader licensing system bars states from imposing their own licensing requirements or sales taxes on reservation commerce conducted by licensed traders (the Warren Trading Post principle). Licensed Indian trader status can be commercially significant in high-volume retail settings — for example, trading posts that sell to non-Indian customers passing through reservation land remain federal licensees subject to BIA rather than state commercial regulation. Most recent amendments: 86 FR 7347 (2021), updating filing procedures.

How It Affects You

If you're an Indian landowner with trust or restricted land: You have the right to lease your land with BIA assistance — BIA must help you identify potential lessees, appraise rental values, and execute a lease that protects your interests. BIA approval is required for any lease to be legally effective. You're also entitled to receive fair market rent unless you choose to accept less (e.g., for leasing to another tribal member or tribal program). If you have co-owners (common through inheritance), the majority consent rule means you may be able to lease even if some co-owners can't be located.

If you're a tribe managing trust land: If your tribe has enacted tribal land leasing regulations and received BIA approval, you may have authority to negotiate and approve certain leases without BIA case-by-case review — streamlining economic development. Tribal approval is always required for leases of tribal trust land (land held for the tribe as an entity, not for individual members).

If you're a developer or business seeking to operate on Indian land: You must obtain a BIA-approved lease — informal agreements or handshake deals with individual landowners are not legally enforceable against the land. Agricultural leases typically run 3–10 years; business leases up to 25 years (longer with tribal approval); energy development leases can run 25–50 years with proper approvals. Plan for BIA review timelines — BIA has statutory obligations to act within specified timeframes but approval can take weeks to months.

If you're a lender considering financing a home or business on Indian land: Long-term residential leases (up to 75 years) can be used as mortgage collateral, making home loans possible on trust land. The Section 184 Indian Home Loan Guarantee Program works with these leases. Business lease assignments require BIA approval.

State Variations

Indian trust land leasing is federal — state land-use laws, zoning, and property tax statutes generally do not apply to trust land. However:

• State environmental laws may apply when a project seeks state permits (e.g., water rights in states that administer water under state law)
• Tribes may enact their own zoning and land-use ordinances governing activities on tribal land
• Oklahoma presents a special case: many Five Civilized Tribes allotments are "restricted fee" land subject to somewhat different rules than standard trust land
• Wind and solar projects on trust land that feed power to interstate grids are subject to FERC jurisdiction for interconnection and transmission

25 CFR Part 226 — Leasing of Osage Reservation Lands for Oil and Gas Mining:

Part 226 governs oil and gas development on the Osage Mineral Estate — one of the most distinctive land tenure arrangements in the United States. The Osage Nation owns the exclusive subsurface mineral estate for all of Osage County, Oklahoma (approximately 1.47 million acres), retained through their 1906 Allotment Act when the tribe chose to hold the mineral estate collectively rather than allot it to individual members. The BIA Osage Agency in Pawhuska, Oklahoma administers the leasing program on behalf of the Osage Nation. Revenue from oil, gas, and other mineral production is distributed as "headrights" to approximately 4,000 Osage shareholders — an unusual per-capita distribution based on inherited fractional shares in the tribal mineral estate. Key provisions:

• § 226.2 — Sale of leases: oil and gas leases on Osage Reservation lands are sold at public auction or through the Osage Tribal Council's designation of available tracts; written applications with nomination fees must precede any tract offering; the Osage Tribal Council has authority to establish the primary lease term (§ 226.10) and set royalty terms within BIA guidelines

• § 226.11 — Royalty payments: lessees pay royalties on oil production to the BIA Osage Agency Superintendent; the royalty rate is established by the Osage Tribal Council and set by BIA in the lease; royalties on gas are separately calculated; all royalties flow through BIA to the Osage tribal fund and are distributed quarterly as headright payments to enrolled Osage shareholders

• § 226.13 — Timing of royalty payments: royalties are due monthly; lessees may submit payments from either the lessee or the purchaser; all payments must be in U.S. currency or approved instrument; late payments accrue interest; the monthly royalty cycle requires detailed production accounting for every producing well on the Osage Reservation

• § 226.16 — Commencement of operations: no drilling or other surface operations may begin on any Osage Reservation tract without a lease covering that tract; pre-lease surface testing (geophysical surveys) requires a separate geophysical permit; lessees must provide prior written notice to surface landowners before any operations begin (§ 226.18)

• § 226.19 — Surface use: lessees have the right to use only so much of the surface as is reasonably necessary for oil and gas operations; surface owners retain all other land use rights; lessees are responsible for compensating surface owners for actual damages caused by operations (§ 226.20)

• § 226.21 — Damage settlement procedure: when surface owners claim damages from oil and gas operations, they submit claims to the Osage Agency; BIA reviews and assists in settlement negotiation; unresolved disputes may be referred to BIA's Office of Hearings and Appeals

• § 226.15 — Unitization: leases may be unitized (combined for coordinated development of a common oil or gas reservoir) with Osage Tribal Council and BIA approval; unitization agreements govern how production is allocated among unitized tracts and how royalties are shared

  The Osage Mineral Estate has produced oil since commercial development began in the 1890s, making it one of the oldest continuously operating oil fields in the United States. The Osage headright distribution system created enormous wealth in the early 20th century (the "Reign of Terror" era, when at least 60 Osage shareholders were murdered by non-Indians seeking to inherit headrights, is memorialized in David Grann's Killers of the Flower Moon and Martin Scorsese's 2023 film adaptation). Today, Osage Reservation oil production is significantly reduced from its peak but remains economically significant; the Osage Nation has sought to expand tribal control over mineral administration through federal trust reform litigation and negotiation with BIA. The trust relationship with the Osage Mineral Estate — with BIA as mineral trustee collecting and distributing revenue — is the subject of ongoing litigation and tribal advocacy for greater self-determination over Osage mineral resources.

25 CFR Part 214 — Leasing of Osage Reservation Lands, Oklahoma, for Mining, Except Oil and Gas:

Part 214 governs the non-oil-and-gas mineral development component of the Osage Mineral Estate — covering hard-rock mining, coal, sand, gravel, limestone, gypsum, and other solid minerals extracted from Osage Reservation lands. While Part 226 governs the dominant oil and gas program (and the headright distribution system), Part 214 addresses the same unique Osage collective mineral ownership but for solid minerals where royalty rates and lease terms differ significantly. The statutory basis is the Osage Allotment Act of June 28, 1906 (34 Stat. 539), which reserved the Osage mineral estate as collective tribal property and authorized the federal government to lease it on the tribe's behalf. Key provisions:

• § 214.2 — Sale of leases: solid mineral leases may be negotiated with the Osage Tribal Council after obtaining permission from the BIA Officer in Charge (the Osage Agency Superintendent); unlike oil and gas leases (which are sold at public auction under Part 226), solid mineral leases may be negotiated directly with a designated company or individual with tribal council and BIA approval — reflecting the specialized market for hard-rock minerals as compared to the commodity market for oil and gas

• § 214.10 — Royalty rates: royalties on solid minerals are set "subject to the approval of the President" (reflecting the original trust relationship codified in the 1906 Act); royalty rates vary by mineral type and are specified in each lease as approved by the BIA; all royalties flow to the Osage tribal fund and are distributed as headright payments to Osage shareholders

• § 214.11 — Payment of rentals and royalties: all rents, royalties, damages, and other amounts due under Osage solid mineral leases must be paid to the Officer in Charge; the BIA Agency then accounts for and distributes the revenue through the headright system — maintaining the same collective ownership structure as Part 226 oil and gas royalties

• § 214.12 — Quarterly royalty payments: solid mineral royalties are due quarterly (January–March, April–June, July–September, October–December payment periods); lessees report production for the quarter and submit royalties within a prescribed period after quarter end

• § 214.13 — Diligence requirements: lessees must exercise diligence in conducting prospecting and mining operations; annual minimum expenditures are required to maintain lease validity; lessees must keep detailed mining records subject to BIA inspection; the diligence obligation prevents lessees from holding Osage mineral acreage speculatively without actual development

• § 214.14 — Surface use: lessees may use only so much of the surface as is reasonably necessary for mining operations; Osage surface allottees retain all other land use rights; lessees are responsible for compensating surface owners for damages caused by mining activity (§ 214.16)

• § 214.15 — Homestead protection: lessees may not conduct prospecting or mining within or upon any homestead selection (individually occupied land that an Osage allottee has designated as a homestead) without written consent of the homestead occupant; this provision protects Osage families living on allotments from having their home parcels disrupted by mining operations

• § 214.17 — Timber use restriction: lessees may not use timber from any Osage lands still subject to federal restrictions on alienation for purposes other than those directly incidental to mining operations; this prevents mining lessees from extracting timber value beyond what the mining activity actually requires

• § 214.18 — Assignment of leases: approved Osage solid mineral leases may be transferred or assigned with consent of both the Secretary of the Interior and the Osage Tribal Council; no assignment is effective until both approvals are obtained — ensuring tribal oversight of who develops Osage mineral resources

• § 214.20 — Annual reports: corporate lessees must file annual reports with the Officer in Charge on January 1 of each year and at other requested intervals; reports cover production volumes by mineral type, royalty calculations, and the lessee's operational plans; the annual report obligation allows BIA to verify royalty accuracy and monitor compliance with diligence requirements

• § 214.21 — Inspection rights: BIA agents and representatives of the lessor may inspect lessee books, records, and mining operations at any time; the BIA audit right is the trust enforcement mechanism that backs up the royalty system; lessees who refuse inspection face lease cancellation

  Part 214's solid mineral program has historically produced significantly less revenue than Part 226's oil and gas operations — the Osage Mineral Estate's subsurface geology is primarily oil-bearing formations rather than hard-rock mineral deposits. Sand, gravel, and limestone production for local construction occurs under Part 214 leases, but the program generates a fraction of the royalties produced by Part 226 oil wells. The importance of Part 214 today is primarily as a complete legal framework ensuring that any solid mineral development on Osage Reservation lands — including potential future coal, limestone, or gypsum extraction — flows through the tribal consent and headright distribution system that protects the Osage collective mineral ownership established in 1906.

25 CFR Part 117 — Deposit and Expenditure of Individual Funds of Members of the Osage Tribe Not Having Certificates of Competency:

Part 117 governs how the BIA Osage Agency Superintendent controls the deposit and authorized expenditure of headright income received by Osage members who do not hold a "certificate of competency" — a legal determination that the individual Indian has the financial knowledge and capacity to manage their own affairs without federal supervision. The certificate of competency system was a core feature of early 20th century federal Indian policy: the federal government acted as a legal guardian for Indians deemed "incompetent" to manage their own finances, holding their funds in supervised trust accounts and approving expenditures. For Osage members, "surplus funds" (headright payments deposited by the BIA after covering basic expenses) were subject to Superintendent approval before disbursement. Key provisions:

• § 117.1 — Definitions: "surplus funds" are the net balance in an Osage member's account after authorized expenditures have been made; "segregated trust funds" are funds set aside from surplus for specific future purposes (education, land purchase) under specific conditions

• § 117.2 — Tax payments: the Superintendent may pay state and local property taxes on restricted Osage property directly from the member's surplus funds; this ensures that Osage members' trust allotments (which are restricted against alienation) do not become subject to tax liens or forfeiture for non-payment — a critical trust protection

• § 117.10 — Vehicle purchase: the Superintendent may authorize up to $2,000 from an adult Osage member's surplus funds for purchase of automotive equipment; this section illustrates the granular supervision the BIA exercised — individual Osage members needed federal approval to buy a car from their own headright income

• § 117.11 — Insurance: the Superintendent may obtain insurance policies on restricted property of minor Osage Indians and pay premiums from the member's funds; this provides basic asset protection for restricted property that the minor cannot independently insure

• § 117.13 — Telephone and telegraph: the Superintendent may pay telephone and telegraph message costs directly from surplus funds for communications necessary to manage the member's affairs; this reflects the era in which the regulation was written and the paternalistic scope of BIA oversight

• § 117.14 — Miscellaneous expenditures: on application by an adult Osage member, the Superintendent may disburse surplus funds for general living expenses, medical care, education, and similar needs; the application requirement means an Osage adult had to ask the BIA Superintendent for permission to spend their own income on everyday necessities

• § 117.17 — Inactive accounts: when an adult Osage member's surplus fund balance is below $300 and there is no likelihood of income resuming, the Superintendent may treat the account as inactive; funds in inactive accounts are held pending application or death

• § 117.18 — Segregated trust funds: withdrawal and payment of segregated trust funds (earmarked for specific purposes) requires application and satisfactory proof that the purpose for which funds were segregated has been accomplished or no longer applies

• § 117.19 — Debts of Indians: debts of Osage members will not be paid from their supervised funds without specific federal authorization; this prevents creditors from seizing headright income through the BIA trust account system — a protection that was critical given the extensive fraud and manipulation targeting Osage headright income in the early 20th century

• § 117.21 — Attorney fees: payment of attorney fees from an Osage member's surplus funds requires BIA approval of both the employment of the attorney and the fee amount; this gatekeeping provision was designed to prevent predatory legal arrangements but also limited Indians' access to independent legal counsel

  Part 117 is a relic of a guardianship era that has been substantially reformed — most of its operative provisions have been superseded by the Indian Self-Determination Act (1975), AIPRA (2004), and the Cobell settlement (2012), which gave Indian people substantially more control over their own trust funds. The certificate of competency system itself has been largely abandoned as a policy matter; BIA no longer actively manages individual expenditures for competent adults the way Part 117 contemplated. The regulation's historical significance lies in documenting the legal architecture through which the federal government exercised extraordinary financial control over individual Osage members at the height of the headright wealth era — control that was systematically exploited by guardians and government officials in the fraud and murder campaign documented in Killers of the Flower Moon.

25 CFR Part 227 — Leasing of Certain Lands in Wind River Indian Reservation, Wyoming, for Oil and Gas Mining:

Part 227 governs oil and gas leasing on the Wind River Indian Reservation in Wyoming — the homeland of the Eastern Shoshone Tribe and the Northern Arapaho Tribe. The Wind River Reservation covers approximately 2.2 million acres in central Wyoming and contains significant oil and gas resources, particularly in the Riverton area and the Wind River Basin. Unlike the Osage Mineral Estate (where the tribe collectively owns the subsurface), Wind River oil and gas leasing applies to lands where individual allottees or the tribe hold mineral interests. Key provisions:

• § 227.1 — Definitions: the "superintendent" means the BIA superintendent for the Wind River Agency or other authorized BIA officer; the definition establishes the BIA official through whom all lease administration flows for Wind River oil and gas

• § 227.2 — Applications for leases: lease applications are submitted to the superintendent; the BIA then processes the application following the general competitive bidding or negotiated lease procedures under applicable federal Indian mineral law

• § 227.10 — Minerals other than oil and gas: unreserved, unallotted Wind River Reservation lands that have not been leased for oil and gas under the Act of August 21, 1916 may be leased for other mineral development; this provision preserves the tribe's and allottees' rights to lease for solid mineral development under a parallel authority

• § 227.11 — BLM coordination: the Bureau of Land Management receives a copy of each lease signed by the Secretary of the Interior; this coordination requirement ensures BLM's federal royalty management system (ONRR) can track and audit production from Wind River Indian mineral leases alongside federal non-Indian leases in the Wind River Basin

• § 227.12 — Mineral reserves in nonmineral entries: where lands have been leased under the 1916 Act and a subsequent homestead or other entry (nonmineral) has been made on the same tract, the mineral rights are reserved; the surface and subsurface ownership are severed — the entrant gets the surface, the tribe or allottees retain the mineral estate

• § 227.14 — Government purchase right: the federal government reserves the right to purchase oil and gas from Wind River Reservation production "in time of war or other public emergency"; this strategic purchase authority traces to World War I-era energy security concerns and remains in the regulation as a federal reserve power

• § 227.15 — Payment of royalties: all royalty payments flow to the BIA superintendent for the benefit of the Shoshone Indian Tribe (and, by extension, the Northern Arapaho) in accordance with the lease terms; royalties are deposited to tribal accounts administered by the Office of Special Trustee

• § 227.17 — Rents and royalties: lessees pay advance annual rent from the lease execution date; upon discovery of oil and gas in paying quantities, advance rent credits against royalties; standard royalty rates apply as set by the lease and BIA policy (currently 16.67% for oil and gas on Indian lands, paralleling the federal onshore rate)

• § 227.18 — Free gas use: if the leased premises produce gas in excess of the lessee's operational requirements, the lessor (the tribe or allottees) may take and use gas without charge for their own domestic needs; this "free use gas" right is a traditional benefit of oil and gas leases on Indian lands, providing energy cost savings to the community

• § 227.19 — Division orders: lessees may arrange for purchasers to pay royalties directly to the superintendent; division orders document the proportional shares of production among all interest holders (the lessor, the lessee, and any working interest owners); the superintendent reviews division orders to ensure tribal/allottee shares are correctly calculated

  The Wind River Reservation is one of Wyoming's largest oil and gas production areas. Production from Wind River Indian mineral leases generates tens of millions of dollars annually in royalties for the Eastern Shoshone and Northern Arapaho tribes, making mineral development a critical economic pillar for both nations. The shared-reservation arrangement — the Northern Arapaho were placed on the Shoshone reservation in 1878 without the Shoshone's consent — creates complex jurisdictional and revenue-sharing questions that Part 227 does not fully address; revenue allocation between the two tribes has been the subject of separate tribal compacts and BIA administrative decisions.

Mineral Leasing on Tribal and Allotted Indian Lands (25 CFR Parts 211 and 212)

25 CFR Part 211 governs leases of tribally owned trust lands for mineral development; 25 CFR Part 212 governs leases of individually allotted Indian lands for the same purposes. The two rules are structurally parallel — Part 212 incorporates many Part 211 standards by reference — but differ in who holds the mineral interest and whose consent is required.

Part 211 — Tribal Mineral Leasing (25 U.S.C. § 396a):

• § 211.20 — Leasing procedures: tribes (through their tribal council) may lease tribal minerals through competitive bidding or negotiated leases; the tribal council must adopt a resolution authorizing the lease; the BIA Area Director or Superintendent approves leases on behalf of the Secretary; tribes with approved energy resource agreements (TERAs under the Energy Policy Act of 2005) may bypass BIA approval and execute leases independently
• § 211.22 — Subsurface storage: the Secretary may approve leases allowing subsurface storage of oil or gas in tribal formations — converted depleted reservoirs or aquifer formations on tribal trust land used for seasonal gas storage — with tribal consent; storage leases are an emerging revenue opportunity for tribes with depleted oil reservoirs
• § 211.24 — Bonds: lessees must furnish performance bonds in amounts set by the BIA; a bond from an approved surety company or cash deposit must be maintained throughout the lease; additional bonding may be required for particularly sensitive areas or large-scale operations
• § 211.27 — Duration: primary terms not to exceed 10 years; automatic extension in paying quantities; suspension rights during market disruptions or force majeure
• § 211.28 — Unitization: the BIA may approve unitization of tribal and allotted tracts with adjacent non-Indian tracts for efficient reservoir management; unitization is particularly important in formations (like the Bakken or Permian Basin) where Indian and non-Indian acreage is interspersed

Mineral Leasing on Allotted Indian Lands (25 CFR Part 212)

While Part 162 governs surface leasing for agriculture, housing, and business, 25 CFR Part 212 governs leases of individually allotted Indian lands specifically for mineral development — oil, gas, geothermal resources, and solid minerals — under the authority of 25 U.S.C. § 396.

Part 212 applies to allotted land (land originally granted to individual Indians under the Dawes Act and its successors) as opposed to tribally owned trust land; the distinction matters because consent requirements differ. Key provisions:

• § 212.20 — Leasing procedures: applications for mineral leases must be filed with the BIA superintendent having jurisdiction over the allotted land; Indian mineral owners may negotiate leases directly with prospective lessees and present the negotiated lease to BIA for approval; unlike Part 162 surface leasing, Part 212 gives mineral owners substantial latitude to negotiate terms rather than requiring competitive bidding in all cases
• § 212.21 — Secretarial execution: the Secretary of the Interior may execute a mineral lease on behalf of an Indian allottee only when the owner is deceased, a minor, or under a legal disability — the rule strongly prefers owner-directed leasing over federal paternalism; guardians or representatives of incapacitated owners must present BIA with their legal authority before executing leases
• § 212.24 — Bonds: lessees must post performance bonds before commencing operations; bond requirements for Part 212 mineral leases are incorporated by reference from 25 CFR Part 211 (tribal mineral leasing), which specifies minimum bond amounts by operation type and scale
• § 212.27 — Lease duration: primary terms and extension conditions are governed by Part 211 standards; oil and gas leases typically have a primary term of 5–10 years with automatic extension if production is occurring in paying quantities; lessees must maintain continuous operations or the lease terminates
• § 212.28 — Unitization and communitization: BIA may approve unitization agreements (combining multiple tracts into a single operating unit) and communitization agreements (pooling small tracts to form a drilling unit of sufficient size); unitization promotes efficient resource recovery and protects allottee interests when their land is part of a larger oil field
• § 212.57 — Royalties: royalty rates for allotted land mineral production are set in the lease terms; historically 12.5% for oil and gas (the same as federal onshore leases); BIA must approve any royalty rate reduction; royalties are paid to the BIA's Office of the Special Trustee for American Indians (OST) and credited to individual Indian money (IIM) accounts

The allotted land mineral leasing system under Part 212 sits alongside — but is legally distinct from — tribal mineral leasing under Part 211. Where Part 211 applies to tribally owned trust land with tribal council authorization, Part 212 applies to individual allotments where the owner's consent governs. In oil and gas producing regions like Oklahoma, North Dakota (Bakken), and New Mexico, Part 212 allotment leases cover significant production: the OST manages IIM royalty receipts for tens of thousands of individual Indian mineral owners, many of whom hold fractional interests in producing allotments across multiple formations.

25 CFR Part 215 — Lead and Zinc Mining Operations and Leases, Quapaw Agency:

Part 215 governs a uniquely specific mining program — lead and zinc mining on allotted Indian lands within the jurisdiction of the Quapaw Agency in northeastern Oklahoma, the heart of the historic Tri-State Mining District (Oklahoma, Kansas, and Missouri) that was once one of the world's largest lead and zinc producers. The Quapaw Tribe (now the Quapaw Nation) holds allotted lands sitting atop massive galena (lead sulfide) and sphalerite (zinc sulfide) deposits that powered the Allied war effort in World War II. Today, the Tri-State district is home to the Tar Creek Superfund site, one of the most severely contaminated mining sites in the United States, where decades of open-pit mining left 75 million tons of mine waste (chat piles) and contaminated groundwater with cadmium, lead, and zinc at concentrations far exceeding safe standards. Key provisions:

• § 215.1 — No operations without approved lease: no lead or zinc mining operations may begin on restricted Quapaw Agency lands until the BIA has approved the lease; unauthorized mining triggers trespass liability

• § 215.10 — Renewal of leases on developed lands: where lands have already been leased and lead/zinc has been discovered, the lessee may apply for renewal on terms consistent with the development value; renewal preserves the lessee's investment in exploration and development while ensuring the Indian landowner receives continuing royalties

• § 215.11 — New leases after forfeiture or abandonment: if a prior lease was forfeited or abandoned, BIA may offer the tract for re-leasing; the new lease must be on terms as favorable to the Indian landowner as the original lease or better — this anti-lowballing protection is essential given the fractionated ownership of many Quapaw allotments

• § 215.13 — Bond requirements: every mineral lease under Part 215 must be accompanied by a performance bond ensuring compliance with lease terms, royalty payment, and site restoration; the historical inadequacy of bond requirements is a major factor in Tar Creek's remediation challenges — bond amounts did not come close to the actual cost of remediating 75 million tons of mine waste

• § 215.14 — Payments to superintendent: all bonuses, rents, royalties, and other payments under Quapaw Agency mineral leases must be made to the BIA Quapaw Agency Superintendent; funds flow through BIA trust accounts to individual Indian money (IIM) accounts for Quapaw allottees

• § 215.16 — Corporate lessee requirements: corporate lessees must file a sworn statement of authorized capital stock, certificates of authority to do business in Oklahoma, evidence of who controls the corporation, and a list of officers and directors; these disclosure requirements are designed to prevent anonymous corporate entities from circumventing Indian landowner protection provisions

  The Part 215 program's historical significance is vast but tragic. The Tri-State Mining District produced nearly $2 billion in lead and zinc during World War I and II — wealth that flowed primarily to non-Indian lessees and mining companies rather than to Quapaw allottees, who received royalties at rates set during an era of documented underpayment and mismanagement. The Tar Creek Superfund site (designated 1983) covers 40 square miles in Ottawa County, Oklahoma; the chat piles contain toxic concentrations of heavy metals that have contaminated the groundwater of Picher, Oklahoma (now largely abandoned after EPA bought out most residents). The Quapaw Nation has emerged as a key environmental steward in the Tar Creek region, operating a tribal environmental program and receiving EPA technical assistance grants to address legacy contamination on tribal lands.

25 CFR Part 225 — Oil and Gas, Geothermal, and Solid Minerals Agreements:

Part 225 implements the Indian Mineral Development Act of 1982 (25 U.S.C. § 2102), which gave tribes and individual Indian mineral owners an alternative to traditional BIA-administered leases: the minerals agreement. Where a traditional mineral lease (under Parts 211, 212, 213, or 226) is a straightforward landlord-tenant arrangement with fixed royalties, a minerals agreement is a more flexible contract — potentially a joint venture, production sharing arrangement, service contract, or other creative structure — that the tribe or individual Indian negotiates directly with an energy company, subject to Secretarial approval. Key provisions:

• § 225.20 — Authority to contract: any Indian tribe may enter a minerals agreement subject to approval of the Secretary and any limitation in its constitution; individual Indian mineral owners may participate with BIA assistance; the tribal sovereignty framing reflects the IMDA's self-determination purpose — tribes initiate and negotiate, BIA reviews and approves

• § 225.21 — Negotiation procedures: an Indian mineral owner may ask the Secretary for advice, assistance, and information about potential developers before or during negotiations; BIA is available as advisor and facilitator, not as the primary negotiating party

• § 225.22 — Approval of minerals agreements: the Secretary must approve or disapprove a submitted minerals agreement within 180 days; disapproval requires written explanation of specific deficiencies; if BIA fails to act within 180 days, the agreement is deemed approved — this deemed-approval provision prevents BIA inaction from blocking tribal economic development

• § 225.23 — Economic assessments: the Secretary shall prepare or commission an economic assessment of any minerals agreement before approval, evaluating whether the agreement provides terms at least as favorable as those achievable under a competitive lease — protecting the tribe from accepting below-market deals due to information asymmetry

• § 225.24 — Environmental studies: the Secretary must ensure all required environmental studies (NEPA, NHPA, ESA consultation) are completed before approving a minerals agreement

• § 225.25 — Dispute resolution: every minerals agreement must contain dispute resolution provisions; no standard procedure is mandated, but the agreement may not strip the Secretary of authority to verify royalty payments

• § 225.26 — Auditing and accounting: the Secretary and ONRR may audit any minerals agreement to verify production volumes, sales prices, and royalty calculations

  The IMDA minerals agreement pathway is particularly valuable for tribes pursuing large-scale or novel resource development. Joint venture agreements — where the tribe takes an equity stake rather than just royalties — allow a tribe to participate as a development partner rather than a passive royalty recipient. The 180-day deemed-approval provision is a crucial self-determination tool: it converts BIA inaction from a development blocker into automatic approval, changing BIA's incentive structure from passive gatekeeping to active review. Several tribes have used IMDA agreements to structure natural gas processing joint ventures, coal mine operations, and geothermal development.

Statutory Authority

This rule implements:

• 25 U.S.C. § 380 — General leasing authority for Indian lands; Secretary may authorize leasing of trust lands
• 25 U.S.C. § 415(a) — Long-term leasing authority: tribes may lease trust land for up to 25 years, renewable once; longer terms (up to 99 years) with tribal council approval
• 25 U.S.C. § 4211 — American Indian Agricultural Resource Management Act: BIA obligations to manage Indian agricultural land for landowner benefit; preference for Indian lessees; fair market rent requirements

Recent Rulemakings

The 2016 comprehensive revision of Part 162 was the most significant update in decades — restructuring all four lease-type subparts, adding the wind/solar subpart (Subpart E) to address the growth in renewable energy development on Indian land, streamlining tribal self-governance provisions to allow tribes with approved leasing regulations to bypass BIA case-by-case review, and clarifying the fractionated ownership consent rules. Prior to the 2016 rule, BIA processed lease approvals under legacy regulations that were widely criticized as too slow for economic development purposes.

Recent Developments

• Renewable energy leasing acceleration (2023–2026): BIA and DOI have prioritized streamlining Indian land leasing for wind and solar development following the Inflation Reduction Act's clean energy incentives. Several large-scale solar and wind lease applications on tribal trust lands — particularly in the Southwest and Great Plains — have moved through BIA review on accelerated timelines under Subpart E. Tribes with approved leasing regulations (HEARTH Act authority) have moved most quickly.
• HEARTH Act adoption increasing: The Helping Expedite and Advance Responsible Tribal Homeownership Act of 2012 (HEARTH Act) allows tribes to approve their own leasing regulations, enabling lease execution without BIA case-by-case approval. As of 2025, dozens of tribes have had HEARTH Act regulations approved by the Secretary of the Interior. The HEARTH Act pathway has become the preferred route for economically active tribes because it cuts BIA review timelines from months to weeks.
• Fractionated ownership and land consolidation: BIA continues administering the Land Buy-Back Program for Tribal Nations (originally funded by the 2012 Cobell settlement) to address fractionated heirship land — allotments divided among hundreds or thousands of co-owners through successive inheritance. Fractionation makes productive leasing nearly impossible without unanimous or supermajority consent. The Buy-Back Program has acquired significant acreage, though hundreds of thousands of fractionated tracts remain.
• Tribal energy resource agreements: The Energy Policy Act of 2005 created Tribal Energy Resource Agreements (TERAs) — a pathway for tribes to independently manage energy resource development on tribal land without BIA oversight. TERA-approved tribes can enter energy leases, rights-of-way, and business agreements directly. DOI has approved several TERAs; more tribes are exploring the option as energy development opportunities increase.

Pending Action

Clean energy lease streamlining remains an active priority at DOI for tribes that have not yet adopted HEARTH Act leasing regulations — BIA is developing model leasing regulations tribes can adapt rather than drafting from scratch. The Indian Land Buy-Back Program for Tribal Nations, originally funded by the 2012 Cobell settlement, has expended most of its appropriated funds; advocacy groups and tribal coalitions have sought additional Congressional appropriations to continue fractional interest acquisition. Tribes exploring Tribal Energy Resource Agreements (TERAs) for independent energy resource management should engage BIA's Energy and Mineral Development Program, which provides technical assistance for TERA applications.