FAQ

Oil and Gas Leasing FAQ

Everything you need to know about the federal onshore oil and gas leasing program

Energy & Natural Resources, Oil and Gas, Public Lands Management, | Analysis

May 5, 2026 | 15 min read | Print Article

Below, you can find answers to several frequently asked questions (FAQs) primarily focused on onshore federal oil and gas leasing to help you understand how the leasing system works, what recent legislation and rules have been implemented, and what all of this means for taxpayers.

For more in-depth information, visit our page on how recent reforms to the federal leasing system modernized it and secured a fair return for taxpayers.

What is the federal oil and gas program? And who runs it?

As its name implies, the Bureau of Land Management (BLM) under the U.S. Department of the Interior (DOI) is responsible for managing 245 million acres of land owned by the federal government. This includes managing all activities on the land, from recreation and conservation to grazing and the production of natural resources like hardrock minerals, coal, oil, and natural gas. The federal government also owns development rights underneath private lands, so the BLM manages 700 million acres of “mineral estate.” The BLM’s rules and processes for managing how companies explore for and develop oil and natural gas on federal lands are referred to as the “federal oil and gas program.”

As part of the program, the BLM holds lease sales that determine who gets exploration and development rights to parcels of federal land, issues rules for responsible development and cleanup, and conducts enforcement activities to ensure compliance. At the end of fiscal year 2025, the BLM was managing around 31,833 leases covering nearly 21.4 million acres of federal land. The leases are primarily concentrated in five western states (Colorado, Montana, New Mexico, Utah, Wyoming) and Alaska, where leases are in the National Petroleum Reserve-Alaska (NPR-A) and operate under separate rules. This FAQ mostly describes the federal oil and gas program in the Lower 48 states.

In 2024, roughly 12.6.% of oil and 9.1% of natural gas produced in the U.S. came from federal lands.

What do federal and state taxpayers get from the federal oil and gas program?

By law, it is federal policy that taxpayers must receive “fair market value for the use of public lands and their resources.” The federal oil and gas program tries to collect this value for taxpayers at separate points in the leasing process:

Bonus Bid Revenue: To capture the value of the right to explore for and develop federal oil and gas resources, the BLM sells leases to the highest bidder in a live auction.
Rent: To capture the value of holding onto federal land (and preventing some other uses of it), the federal government charges lease holders rent.
Royalty Rate: To capture the value of the oil and gas itself, the BLM charges operators a set percentage of the resources’ value when they sell the oil and gas to others.

Nearly half (49%) of all revenue generated by federal oil and gas leases is shared with the states where the leases are located. Aside from direct revenues, oil and gas development on federal land also benefits taxpayers by supporting economic activity.

What is a federal oil and gas lease sale?

To find a more detailed walkthrough of the leasing process, read our Oil and Gas Leasing 101.

The Secretary of the Interior is required to hold lease sales at least quarterly in every state where unleased lands are eligible under the Mineral Leasing Act of 1920. Lease sales are now held through a commercial online website called EnergyNet.

The lease sale process begins with public nominations of available lands to be included in a sale—known as “Expressions of Interest (EOI).”. The BLM state office considers these nominations and conducts an environmental review. Based on that review, the state office then issues a notice of sale, with a period for public comments or formal protests on the proposed leases. After the comment period, the state office publishes the final list of tracts available for lease and opens online bidding.

Lands that are offered for sale go through a competitive bidding process and the legal minimum for a bid, also known as the bonus bid, is set at $10/acre. Companies who win the bid must pay the BLM an application fee, the bonus bid amount, and the first year’s rent priced at $3/acre.

Over the course of the lease, lessees must pay rent during periods of nonproduction–$3/acre for the first two years of the lease, $5/acre for years 3-8 of the lease, and no less than $15/acre for years 9-10. Once production begins, lessees no longer pay rent and instead pay a royalty on the value of total oil and gas produced. The statutory minimum for royalty rate is currently set at 12.5%.

However, not all lands offered for sale get bid on and the ones that did not would be available for noncompetitive leasing for 2 years. Oil and gas operators can file for a noncompetitive offer and, if accepted, only have to pay the $3/acre first year’s rent and an administrative fee.

What changes or reforms to the leasing program have recently been implemented?

On January 27th, just one week after taking office, President Biden signed Executive Order #14008, Tackling the Climate Crisis at Home and Abroad, and paused new oil and gas lease sales on public lands and in offshore waters. The DOI was ordered to conduct a comprehensive review of permitting and leasing practices, which would include reconsidering the royalty rates for coal, oil, and gas. The executive order did not pause any other aspects of oil and gas development, including applications for permits to drill (APD) or production, which usually takes place after land parcels have already been leased. The pause was lifted by court injunction in June 2021.

Through the Unified Agenda of Regulatory and Deregulatory Actions, released in June 2021, the Biden Administration signaled that it would use agency authority to reform the leasing system, which was likely tied to the ongoing DOI review at the time. The DOI issued their federal leasing report in November 2021 after the comprehensive review, further reaffirming the need for reform.

In August 2022, the Inflation Reduction Act (IRA) introduced significant changes for oil and gas leasing over the next ten years. Under these reforms, the federal onshore royalty rate was set at 16.67% until August 2032. Rental rates were raised to $3/acre for the first two years, $5/acre for years three to eight, and then no less than $15/acre for years nine and ten; and the minimum bid was raised to $10/acre. The IRA also abolished noncompetitive leasing and implemented an expression of interest fee of $5/acre for entities nominating land for competitive lease sales.

In April 2024, BLM released a final oil and gas leasing rule which codified many of the provisions passed in the IRA, in addition to implementing new reforms. The rule increased the minimum bond amount to $150,000 for a single well, $500,000 for a statewide bond, and eliminated nationwide and unit bonds. The rule will also help direct leasing to appropriate locations by instituting preference criteria. For more information on the final oil and gas leasing rule, see our analysis here.

However, much of these long overdue and common-sense reforms are either rolled back or at risk of being repealed. The FY2025 budget reconciliation bill, also known as the One Big Beautiful Bill Act (OBBBA), passed on July 4^th, 2025, reversed most of the changes to federal onshore oil and gas leasing program made in the IRA. The law lowered the royalty rate to the outdated 1920s rate of 12.5%, reinstates noncompetitive leasing, and eliminated the expression of interest fee. OBBBA further mandates DOI offer no less than 50% of available, nominated parcels within 18 months of a parcel getting nominated. DOI is also required to hold a replacement sale if 25% or less of the offered acreage does not receive a bid.

In the Spring 2025 Unified Regulatory Agenda—the Administration’s rulemaking calendar that maps out each agencies’ top priorities for the next six month—DOI announced its intent to repeal 2024 oil and gas leasing rule and revert to bonding policies established in the 1960s, leaving taxpayers once again exposed to billions in cleanup liabilities.

Why does TCS support these leasing reforms?

For decades, TCS has raised the alarm that many provisions of the oil and gas leasing program were woefully out of date and were preventing taxpayers from receiving a fair return on investment. For most of the last century, the federal government has allowed the oil and gas industry to profit from the sale of taxpayer-owned resources without adequately compensating taxpayers. Until this year, the federal government’s fees were outdated and well below the market rate; the federal government charged a 12.5% royalty, a rental rate of $1.50/acre or $2/acre, and a minimum bid of $2/acre. Taxpayers had been losing money at every step of the oil and gas leasing process. We believe that taxpayers win when we fix the broken and outdated leasing system and bring it into the 21^st century.

What are the costs of repealing these reforms?

America’s public lands and natural resources are owned by taxpayers who deserve to be fairly compensated for the extraction and sale of such resources. IRA updated the statutory minimum for royalty rate from its 1920s rate to 16.67%, a rate more in line with what many oil and gas producing states charge. New Mexico charges 18.75% and Texas charges up to 25%. But OBBBA reverted this rate to the old 12.5%, and as a result TCS estimated that taxpayers have lost over $1 billion in projected revenue from leases sold since July 4, 2025, due to the reduction of royalty rate in OBBBA. Mandating DOI offer more public land for oil and gas development did not and will not translate into better returns for taxpayers. Leasing public lands at below-market royalty rates will only lock taxpayers into bad deals for decades to come.

Weakening bonding requirements will expose communities to the health and safety risks of orphan wells and taxpayers to billions in potential cleanup liabilities. To extract valuable oil and gas resources from federal land and sell them for profit, oil and gas operators are required to reclaim wells and surrounding sites after operation ceases. BLM requires operators to post a bond or other forms of financial assurance to ensure that they will perform their reclamation obligations, otherwise they will have to forfeit their bonds. BLM uses reclamation bonds to recuperate at least some of the cleanup costs if operators abandon their wells or go bankrupt. When minimum bond amounts fall short of actual reclamation costs, federal taxpayers can be left to shoulder billions in cleanup costs. And when oil and gas wells are left unreclaimed, they can leak methane, contaminate drinking water, and put nearby communities at risk.

Cleanup is costly—BLM estimates that the cost to plug a well and reclaim the surface ranges from $35,000 to $200,000, with an average cost of $71,000. For decades, bond minimums fell far short of actual cleanup costs, and was set at $10,000 for an individual lease bond, $25,000 for a statewide bond, and $150,000 for a nationwide bond. Before the 2024 rule updated bond minimums, there was a $6.15 billion shortfall between how much BLM held in bonds and how much cleanup would cost—the potential reclamation costs that taxpayers will have to shoulder.

Revering back to the old bonding minimums—that had not been adjusted for inflation since they were first set in the 1950s and 1960s—will once again expose taxpayers to the costly liabilities of well cleanup and leave communities vulnerable to the public health and safety threats of unreclaimed wells.