Who guarantees the work: the financial assurance rule, and the proposal to shrink it

Every decommissioning scope a contractor bids is a promise by someone else to pay for it. Financial assurance is the rule that decides whether that promise is backed by anything.

It is also, right now, unsettled. A 2024 final rule tightened the requirement substantially. A proposal published in March 2026 would significantly loosen it. Neither changes a single plugging or removal obligation. Both change who is good for the money.

For a service company, that is not an abstract policy question. It is the difference between an operator that can fund a campaign and one whose scope eventually arrives as an orphan.

The gap that drives everything

Start with the number that has not changed.

The Government Accountability Office reported that as of June 2023, the regulator held about $3.5 billion in supplemental bonds against total estimated decommissioning costs of $40 billion to $70 billion.

That is not a rounding problem. It is a structural exposure, and it has been documented for a decade. GAO’s earlier work found that as of October 2015, of $38.2 billion in decommissioning liabilities, the Department held or required about $2.9 billion in financial assurance and had foregone requiring about $33.0 billion for most of the remainder.

The mechanism for that forgoing was a financial strength test. A lessee that passed it was not required to post a bond. The theory is sound when the lessee stays solvent. Fieldwood is what the theory looks like when it does not, and our predecessor liability analysis traces where the work goes next.

Roughly $3.5 billion in bonds against $40–70 billion in liabilities. Both the 2024 rule and the 2026 proposal are arguments about how much of that gap the government should carry.

What the 2024 rule did

The final rule was announced on 15 April 2024, broadly consistent with a June 2023 proposal. It revised the criteria for deciding whether oil, gas and sulfur lessees, right-of-use and easement grant holders, and pipeline right-of-way grant holders must provide supplemental financial assurance above the minimum base bond.

Two tests became the gateway.

Credit rating. A company is not required to secure supplemental financial assurance if it holds an investment-grade credit rating from a nationally recognised statistical rating organisation — greater than or equal to BBB- from S&P or Baa3 from Moody’s, or the equivalent.

Proved reserves. Alternatively, if a lessee meets a minimum proved-reserves-to-decommissioning-liability ratio of 3 to 1, it can avoid supplemental assurance for the lease associated with those reserves and that liability.

The rule also permitted third-party guarantees for supplemental bonding purposes.

BOEM estimated the result would be about $6.9 billion in new supplemental financial assurance across the OCS.

Note what the two tests actually measure. A credit rating is a judgment about the company. A 3-to-1 reserves ratio is a judgment about the lease. Neither is a judgment about whether the specific platform in front of you will be removed on time.

What the March 2026 proposal would do

On 9 March 2026, responding to Executive Order 14154, BOEM published a proposed rule with the stated purpose of significantly reducing the supplemental financial assurance required from OCS oil, gas and sulfur lessees, and thereby increasing capital available for exploration and production.

The principal proposed changes:

• Lower the credit-rating bar. From investment grade to BB- from S&P or Ba3 from Moody’s — a move from the investment-grade floor into speculative grade.
• Count predecessors. Allow the financial strength of predecessors to be considered when deciding whether a current lessee must provide supplemental assurance.
• Ease the alternatives. Remove restrictive provisions governing third-party guarantees and decommissioning accounts.

The estimated effect is a reduction of roughly $484 million a year in compliance costs against the 2024 baseline. A 60-day comment period followed publication. As of this writing the proposal has not been finalised, and the 2024 rule remains the operative standard.

Reading the predecessor provision carefully

The predecessor change deserves more attention than it has received, because it cuts in two directions.

Under the Outer Continental Shelf framework, decommissioning obligations run with the lease and reach back through prior owners. That joint and several reach is why a solvent predecessor can end up performing work on infrastructure it sold years earlier — the dynamic at the centre of the Fieldwood estate.

Allowing a predecessor’s financial strength to reduce the current lessee’s bonding requirement is therefore internally consistent: the government is already relying on that predecessor as a backstop, so requiring a bond as well arguably double-counts the security.

The commercial consequence is less comfortable. It means less cash and surety standing in front of the work, and more reliance on a legal claim against a company that may be several transactions removed from the asset. Claims take years. Vessels and crews do not wait years.

For a contractor, the practical translation is that the identity of the predecessor becomes a commercial fact about the account, not just a legal footnote.

What this does and does not change

Unchanged. Plugging requirements under 30 CFR 250.1715. Removal deadlines. The Idle Iron clock. Site clearance and certification. Financial assurance governs security for performance, not the performance standard itself.

Changed, or changing. How much cash and surety sits behind the obligation. Which operators must post it. Whether a speculative-grade balance sheet is sufficient. How much weight a predecessor’s strength carries.

Also in motion. Both rules are BOEM rules, and BOEM no longer exists as a separate bureau: Secretary’s Order 3451 combined BOEM and BSEE into the Marine Minerals Administration on 10 July 2026, with all existing regulations remaining in force. Expect citations in this area to carry both names for some time.

GAO’s January 2024 report on decommissioning enforcement also listed completing financial assurance reforms — requiring higher supplemental bonding and addressing known weaknesses — as one of four recommendations, and marked it a priority. The 2026 proposal moves in the opposite direction from that recommendation. Both documents are part of the public record a supplier may need to cite.

How a contractor should use this

Financial assurance is one of the few genuinely forward-looking signals available in the public record. A removal deadline tells you when work is due. A bonding position tells you something about whether it will be funded.

1. Check the rating, not the reputation. Investment grade and speculative grade are a one-notch distinction under the proposal. BB- is not BBB-. Ask which it is.
2. Ask what the assurance rests on. A bond, a third-party guarantee, a decommissioning account and a passed financial strength test are not equivalent protections for a contractor’s receivable.
3. Identify the predecessors. If the proposal is finalised, predecessor strength may be doing work that a bond used to do. Know whose balance sheet is actually behind the scope.
4. Watch the reserves ratio. A 3-to-1 proved-reserves test is sensitive to price. A ratio that clears comfortably at a high oil price can fail at a lower one — the mechanism we traced in what an oil price shock does to the decommissioning clock.
5. Price the payment risk. Progress terms, retention and escrow are the contractor’s own financial assurance. Thin operator security is a reason to tighten them, not a reason to walk.
6. Separate the two files. The reorganisation of the agency and the rewriting of the bonding rule are different events. Do not let one be used to explain the other.

The uncomfortable summary

A tighter rule raises the cost of holding mature assets, which can push marginal operators to sell or surrender — and selling is what creates the pre-execution windows suppliers watch for. A looser rule frees capital, keeps assets in weaker hands longer, and leaves a larger share of the $40–70 billion exposure sitting behind legal claims rather than cash.

Neither outcome removes the work. Both change who pays for it, and when. A contractor’s interest is narrower and more practical than the policy debate: for this account, on this lease, is the obligation backed by something I could collect against?

That question is answerable from public filings, and it belongs in the qualification stack alongside structure counts and permit dates. It is a standing item in a one-off Opportunity Brief.

Sources

• Federal Register, Risk Management and Financial Assurance for OCS Lease and Grant Obligations, proposed rule published 9 March 2026.
• Bureau of Ocean Energy Management, Risk Management and Financial Assurance.
• Federal Register, Risk Management and Financial Assurance for OCS Lease and Grant Obligations, proposed rule of 29 June 2023 that preceded the April 2024 final rule.
• U.S. Government Accountability Office, Offshore Oil and Gas: Interior Needs to Improve Decommissioning Enforcement and Mitigate Related Risks, GAO-24-106229, January 2024 — the $3.5 billion in bonds against $40–70 billion in estimated costs, and the financial assurance recommendation.
• U.S. Government Accountability Office, Offshore Oil and Gas Resources: Actions Needed to Better Protect Against Billions of Dollars in Federal Exposure to Decommissioning Liabilities, GAO-16-40 — the October 2015 figures.
• U.S. Department of the Interior, Secretary's Order No. 3451, 10 July 2026.
• Rule-detail summaries of the credit-rating and proved-reserves thresholds, the $6.9 billion estimate and the $484 million annual reduction are drawn from law-firm analyses of the rulemakings, including Bracewell on the 2024 final rule and Bracewell on the 2026 proposal. Verify figures against the Federal Register text before relying on them commercially.