What Oil and Gas Lenders Look For: A Data Checklist

By MercFinancial · Published 2026-07-18

The document checklist energy lenders expect before they price a deal: reserve report, LOE detail, hedge book, title status, and financials, explained item by item.

Oil and gas lenders look for a defensible reserve report, a clean lease operating history broken out by well or lease, a hedge book covering a meaningful share of proved developed producing volumes, title that's free of unresolved defects, and a corporate file with organized financials and ownership documents. Miss any one of these and your file stalls in underwriting instead of moving to term sheet. Have all of them ready and a lender can price a deal in days instead of weeks.

This isn't a mystery list. It's the same package every reserve-based or asset-based energy lender asks for, in roughly the same order, whether you're a two-well operator in the Permian or a service company running a fleet of workover rigs. What varies is how much of it operators actually assemble before they start calling lenders — that gap is where most deals lose weeks.

What follows is the literal checklist. Work through it before you approach a bank, a non-bank energy lender, or a broker like MercFinancial's oil and gas funding desk, and you walk in with a submission-ready package, not a partial one.

"I thought I had a strong deal — decent production, no debt on the leases. Three different lenders asked for the same reserve report and LOE detail before they'd even talk numbers. Once I had it all in one folder, the conversation changed completely."

The Checklist at a Glance: Twelve Items Every Energy Lender Requests

Every energy lender asks for some version of these twelve items, whether the request comes as a formal term sheet condition or an informal "send us what you've got" email.

• Third-party reserve report (SEC or bank-case pricing, dated within the lender's acceptable window)
• Decline curve analysis supporting the reserve report's production forecasts
• Type well data for any undeveloped or recently drilled locations
• Lease operating statements, well-by-well, typically 12-24 months trailing
• LOE per BOE broken out by category (labor, chemicals, workover, saltwater disposal, surface repairs)
• Current hedge positions — instrument type, volumes, strike prices, counterparties, maturities
• Title opinions or a division order title status summary for the units securing the loan
• Executed leases and any JOAs covering the collateral
• Regulatory standing — plugging bonds, permits, and state agency compliance status
• Three years of business financials (tax returns and/or CPA-prepared statements)
• Entity documents and ownership structure — formation docs, operating agreement, cap table
• Debt schedule covering any existing liens, mineral or royalty encumbrances, and payables

None of these individually is exotic. What trips operators up is having half of them current and the other half stale, scattered across different consultants, or never generated in the first place. The sections below explain what "acceptable" looks like for each.

Engineering: Reserve Report, Decline Curves, and Type Wells

The reserve report is the foundation of the underwriting file. It's what a bank's engineering group (or a third-party reviewer they hire) uses to establish your borrowing base — the ceiling on how much they'll lend against proved reserves. For the mechanics of how that number gets calculated, see how reserve-based lending works for oil producers.

What lenders actually check

An engineer reviewing your file checks three things: whether the decline curves match actual production history rather than an optimistic type curve, whether the pricing deck is conservative relative to the strip, and whether proved undeveloped (PUD) locations are reasonably scheduled rather than stacked late in the forecast to inflate present value. A report leaning on aggressive type curves or flat pricing above the forward strip gets discounted or sent back for revision — either way, that costs you weeks.

Financing a discrete drilling or completion program instead of an existing producing base? The same engineering discipline applies, but the emphasis shifts toward offset well performance and type well support — see drilling and completion financing for small operators.

Operations: Lease Operating Statements and LOE per BOE

Lease operating statements (LOS) tell a lender what it actually costs you to keep production flowing, and by extension what cash flow is left to service debt. Lenders want 12 to 24 months of well-by-well LOS, not a rolled-up company total — a rolled-up number hides which wells are dragging on margins and makes it impossible for the lender's engineer to sanity-check your expense assumptions against the reserve report.

The metric that matters most is LOE per BOE (barrel of oil equivalent), which lenders benchmark against basin norms. A well running well above typical LOE per BOE for its area raises questions about mechanical issues, water handling costs, or aging equipment — all of which affect cash available for debt service. Break LOE into its components (labor, chemicals and treating, workover and maintenance, saltwater disposal, surface repairs) before a lender asks you to.

Risk Management: Your Hedge Book and Why Lenders Care

Most reserve-based and asset-based energy lenders require some level of hedging on the volumes securing the loan, often a floor around a set percentage of PDP production for the first several years. The logic: collateral value depends partly on future cash flow, and cash flow depends on price. A hedge book that locks in a portion of expected revenue reduces the lender's price exposure — and yours.

Bring your hedge book in full: instrument type (swap, collar, put), volumes hedged by month, strike or floor/ceiling prices, counterparty, and maturity dates. Lenders compare hedged volumes against your projected production curve to see how much near-term output is actually protected. An unhedged operator isn't automatically disqualified, but expect a mandatory hedging condition at closing or a more conservative borrowing base to compensate.

Price swings themselves are worth understanding on their own terms — if you want the mechanics of how a move in WTI ripples through into your available credit, see how WTI price swings change your borrowing capacity.

Land and Legal: Title, Leases, JOAs, and Regulatory Standing

Engineering and financials get most of the attention, but a clean title package is what actually lets a lender close. They need to know the collateral is really yours to pledge, free of competing claims that could jump ahead of their lien. At minimum, expect a request for:

• Title opinions or a division order title status report on the wells and units securing the loan
• Executed oil and gas leases covering the acreage, including any amendments or extensions
• Joint operating agreements (JOAs) for any non-operated or partially owned interests
• Regulatory standing documentation — plugging bonds, active permits, and confirmation you're in good standing with the relevant state oil and gas commission

Unresolved title defects — a missing heir's signature, an old assignment never recorded, a lapsed lease held by production on a technicality — are among the most common reasons a financially sound deal takes months longer than expected to close. Title diligence gets even more central when you're acquiring producing wells rather than borrowing against ones you already operate; our piece on financing an acquisition of producing oil wells covers what that process looks like.

Financials and Ownership: What the Corporate File Must Contain

Underneath the engineering and land work, lenders still underwrite a business, not just a set of wells. The standard corporate file applies on top of everything above:

• Three years of business tax returns and, where available, CPA-prepared or reviewed financial statements
• Entity formation documents — articles of organization or incorporation, operating agreement or bylaws
• Ownership structure and cap table, including any minority interests or outside investors
• A current debt schedule listing every existing lien, note, mineral or royalty encumbrance, and material payable
• Personal financial statements for any principal signing a personal guarantee

Oilfield service companies and drilling contractors face a different working-capital picture than producers borrowing against reserves — see working capital options for oilfield service companies for financing built around receivables and equipment instead. Sitting on a backlog of unpaid joint interest billings? See JIB factoring: turning joint interest billings into cash.

Red Flags Lenders Screen for Before They Ever Price a Deal

Certain issues cause lenders to slow down or decline before they get anywhere near a term sheet. Knowing them in advance lets you address them before submission rather than explain them after the fact.

Beyond those four, watch for production data that doesn't reconcile between operating reports and state regulatory filings, a debt schedule with undisclosed liens that surface during a title search, and declining cash flow without a clear operational explanation. None of these are automatic disqualifiers — lenders see distressed situations regularly — but an unexplained red flag reads very differently from one you've already gotten ahead of.

How to Use This Checklist With a Broker to Hit 160+ Lenders at Once

Assembling this package once and shopping it broadly beats approaching lenders one at a time and rebuilding the file for each one's format. That's the core value a brokerage adds: instead of learning every lender's submission preferences yourself, a broker who already knows them packages your data once and routes it to the lenders whose current appetite, basin focus, and structure match your deal.

It also removes the guesswork of which lender to approach first. Reserve-based lenders, asset-based lenders, and specialty energy funds all price risk differently, and a package built for one doesn't always translate to another. A broker with relationships across 160-plus wholesale lenders can match your reserve mix, equipment needs, or working-capital gap to the lenders most likely to say yes quickly. If equipment financing is part of your plan, see oilfield equipment: lease or finance — running the numbers.

Frequently Asked Questions

What documents do I need for an oil and gas loan?

At minimum: a current third-party reserve report, 12-24 months of well-by-well lease operating statements, your hedge book if you have one, title opinions or a title status report, executed leases and JOAs, three years of business financials, and your entity formation and ownership documents. Deal size and structure may add items, but this set is the starting point nearly every energy lender requests.

How recent does my reserve report need to be?

Most lenders want a report dated within the last 12 months, and many require an annual update as a condition of an existing loan. An older report is typically treated as stale and discounted heavily or rejected, since production performance and pricing can shift enough in a year to materially change the borrowing base.

Do all energy lenders require hedging?

No, but a large share of reserve-based and asset-based energy lenders require hedging a portion of PDP volumes, often for the first several years of the loan term. Requirements vary by lender and by leverage — a conservatively structured loan may face lighter hedging conditions than a higher loan-to-value deal.

Why do lenders care so much about lease operating expenses?

LOE directly determines how much cash flow is left after operating costs to service debt — that's what actually secures the loan in practice, not just the reserves on paper. A lender who sees rising LOE per BOE without a clear explanation will assume margins are eroding and price the deal more conservatively, or ask for more detail before moving forward.

This article is for educational purposes only and is not financial advice. Loan programs, rates, and approvals vary by lender and borrower profile.