Reserve Report Audit Checklist. 12 criteria. Lender findings in under 3 minutes.

Reserve audit guide

How lenders audit a third-party reserve report

What is a third-party reserve report

A third-party reserve report is an engineering estimate of future recoverable oil, gas, and natural gas liquids tied to a specific property set and an economic forecast. For a public issuer, reserve disclosure is framed by SEC definitions and the company's public filing obligations. For a private borrower, the same engineering concepts usually appear in a bank deliverable, acquisition data room, or annual reserve package. The report normally summarizes reserve categories, forecast production, pricing assumptions, operating costs, capital, taxes, ownership, abandonment costs, and discounted cash flow. It may be prepared by an independent engineering firm or by internal engineers, depending on the context and the requirement in the credit agreement or transaction process.

For a lender, the report is not useful because it is long or because it contains a large PV number. It is useful only to the extent the assumptions can be traced, tested, and translated into repayment capacity. The bank needs to know how much value is in proved developed producing reserves, how much depends on development capital, whether the PUD inventory can be retained under the five-year development expectation, whether ownership assumptions are tied to title support, and whether costs and prices are auditable. A reserve report that does not answer those questions may still be technically sophisticated, but it is weak collateral support.

Why lenders need an independent audit

Reserve reports are built for multiple audiences. Engineers focus on reserve classification and forecast support. Public-company disclosure teams focus on SEC reporting requirements. Borrowers focus on available credit, borrowing-base redeterminations, covenant compliance, and investor communication. Lenders need a narrower product: a list of the report assumptions that can change collateral value, ranked by severity, with specific follow-up requests. That is the purpose of an audit checklist. It does not re-engineer the field. It identifies whether the current report has enough support to underwrite a credit decision.

The lender lens is different from engineer quality control. A decline curve can be mathematically valid and still be poorly supported for credit if the report does not reconcile it to actual production. A PUD location can be technically attractive and still be weak collateral if it lacks funded development timing. A price deck can be reasonable for management planning and still be unusable for a bank if it is not disclosed, or if it cannot be bridged to the lender deck. A title assumption can be ordinary in an engineering model but unacceptable in a loan if the working interest or royalty burden is not tied to lease records. The checklist forces those distinctions into the open before the credit memo is written.

The 12 lender questions to ask

The first question is whether all PUDs are scheduled for development within five years of initial booking, with exceptions documented. The second is whether there is a written PUD development plan with capital, timing, and NRI assumptions. The third is whether PDP decline is consistent with actual production history. The fourth is whether the price deck is explicitly stated as SEC, strip, management, bank, or another basis. The fifth is whether economic limits are disclosed and applied at the well level. The sixth is whether LOE is tied to historical operating data or credible references.

The remaining six questions complete the lender screen. Are NRI assumptions consistent across reserve categories and reconciled to ownership support? Does the report disclose plugging and abandonment cost treatment? Are negative-value wells excluded from proved reserve value or separately identified for lender exclusion? Does the report reconcile year-over-year reserve revisions with causes? Are type curves documented and supported by analog production? Are working interest and royalty assumptions tied to title records? Each question maps to a missing-document request and a borrower or engineer question because a finding is only useful if it can be cleared.

SEC Modernization (33-8995) and what changed in 2009

The SEC's oil and gas reporting modernization rule, commonly cited as Final Rule 33-8995, updated public-company reserve disclosure for fiscal years ending on or after December 31, 2009. It modernized parts of the reserve framework, including treatment of technologies used to establish reasonable certainty, pricing conventions, disclosure by reserve category, and expanded discussion around proved undeveloped reserves. For lenders, the important point is practical: the modern disclosure regime made reserve category support, changes in proved undeveloped reserves, and economic assumptions more visible. That visibility gives credit teams a public-reference basis for asking disciplined follow-up questions.

The checklist uses the SEC modernization rule as a reference point, not as legal advice. A private borrower is not always an SEC registrant, and a loan file is not a Form 10-K. But public disclosure rules are still useful because they define a common language for reserves, economics, development timing, and revisions. When a private report does not include support that a public report would normally discuss, the lender should understand why before relying on the PV. The checklist therefore asks for evidence rather than a bare representation.

Reg S-K Item 1202/1203/1204 walkthrough

Reg S-K Item 1202 covers disclosure of reserves, including important context around quantities, technologies, pricing, and related assumptions. For lender diligence, Item 1202 helps frame questions about price-deck disclosure, ARO treatment, and the basis for net quantities. If the reserve report does not identify the price basis or treatment of abandonment costs, the lender cannot cleanly compare the report PV to a bank-deck value.

Reg S-K Item 1203 addresses changes in proved reserves, including extensions and discoveries, production, revisions, purchases, and sales. It is directly relevant to year-over-year reserve reconciliations. A lender should not accept a large positive revision without understanding whether it came from performance, price, ownership, development timing, acquisitions, or an engineering change. Item 1204 addresses production information and provides another public-reference anchor for tying forecast behavior to operating history.

PUD 5-year rule explained

The PUD five-year issue is often the fastest way to find reserve-report risk. Proved undeveloped reserves generally need a development plan showing that they are scheduled to be developed within five years of initial booking, unless specific circumstances support a longer period. The lender question is not simply whether management intends to drill. The question is whether the report contains enough evidence to support the proved classification and whether the borrower has the capital, permits, inventory control, and operational plan needed to execute. An unfunded PUD schedule can inflate collateral value while producing no near-term cash flow.

Credit teams should ask for a PUD vintage schedule showing initial booking date, expected drill date, current status, and any exceptions. They should compare that schedule to the capital budget and liquidity plan. They should also look for stale locations that repeatedly roll forward without conversion to PDP. If a PUD cannot be developed within the expected window, the lender may still value it for an acquisition or optionality case, but it should not blindly receive proved-reserve borrowing-base treatment.

Common red flags lenders look for

Common red flags include a reserve report that discloses total proved value but hides reserve-category economics, a PUD-heavy reserve mix without a funded schedule, PDP decline assumptions that are smoother than actual production history, missing price-deck labels, absent LOE support, missing ARO treatment, unexplained positive revisions, type curves without analog wells, and ownership assumptions not tied to title. Another red flag is a report that includes high PV wells without showing whether some wells are negative under the disclosed deck. Negative economics matter because the lender is underwriting cash flow and collateral protection, not gross barrels.

The RBL sanity check is not a substitute for a bank model, but it is useful for triage. If a report shows a large current value but the default PDP/PDNP/PUD advance rates produce a much lower borrowing-base estimate, the credit team should understand why. The reason may be a conservative public default, a high PUD share, ARO burden, weak PDP base, or simply missing data. Each case produces a different diligence path. The checklist turns that path into requests and memo language.

When to commission an independent reserve red-flag review

A red-flag review is most useful before a borrowing-base redetermination, acquisition bid, refinance, covenant waiver, or audit committee review. It is also useful when a borrower changes engineers, when proved reserve value changes sharply year over year, when the report becomes more PUD-heavy, when field performance deviates from forecast, or when a lender is asked to increase availability against the same asset base. The review does not need to be a full reserve audit to be valuable. A focused review can identify the handful of assumptions that control lender exposure.

The output should be concrete: severity-ranked findings, missing documents, borrower questions, and memo language. A vague statement that the report needs more support does not help a credit officer. A specific request for a PUD vintage schedule, well-level economic-limit table, PDP production-history reconciliation, WI/NRI title tie-out, or ARO schedule does. That is the discipline this checklist is designed to enforce.

Public references for this checklist include SEC Final Rule 33-8995, Reg S-X 4-10, Reg S-K Item 1202, Reg S-K Item 1203, Reg S-K Item 1204, OCC oil and gas E&P lending guidance, and the public SPE-PRMS 2018 reference page. SPE-PRMS is cited only as a reference and is not reproduced here.