Oil and gas month-end close: Checklist, calendar, and worked examples for energy companies

The oil and gas month-end close is the monthly process of recording production revenue, lease operating costs, partner billings, depletion, and taxes for a period, reconciling every account, and locking the books. It follows the same steps as any month-end close, with extra work driven by physical volumes and shared ownership.

• Working interest (WI) and net revenue interest (NRI)WI is your share of a well's costs. NRI is your share of its revenue after royalties. A 75% WI under a 12.5% royalty gives you a 65.625% NRI.
• Joint interest billing (JIB)The operator pays the well's bills and charges each non-operating partner its WI share every month.
• Prior period adjustment (PPA)The industry term for the true-up you book when a late purchaser statement or JIB differs from your estimate. It's usually a change in estimate booked in the current month, not a GAAP restatement.

Oil and gas accounting is the wider discipline of accounting for exploring, developing, producing, and selling oil and gas, including lease acquisition, reserves reporting, and tax. The month-end close is its monthly cycle.

An oil and gas close starts from physical volumes rather than invoices. You estimate production and prices before purchaser statements arrive, split costs and revenue by working and royalty interest, bill partners through joint interest billing, and book depletion, ARO accretion, and severance taxes. Most of that data comes from operators, purchasers, and pipelines outside your team.

Here's how an upstream exploration and production (E&P) close compares:

Most oil and gas numbers arrive after you close. Purchaser statements often come one to three months after production, operator JIBs up to a month later under COPAS 2005, and Texas production taxes are due the 25th of the next month for oil and the 20th of the second month for gas. That's why the close runs on accruals that later get trued up.

Terms differ by contract and state.

The 1984 and 2005 forms also presume bills are true and correct after 24 months, which limits how far back partner audit exceptions can reach. Exhibit C of your joint operating agreement (JOA), the accounting procedure attached to it, governs which version and which terms apply.

There's no published close benchmark specific to oil and gas. In its August 17, 2026 upstream close checklist, Quorum Software says most finance teams target five to ten business days, a vendor statement with no survey behind it. By that yardstick a 12-day close is slow, and estimating instead of waiting for statements is the main lever for shortening it.

Across industries, Vena's survey of more than 600 US finance professionals, published October 23, 2026, found an average close of 6.2 business days: 4.7 for single-entity teams and 8.3 for teams closing more than 10 entities. If you close many joint venture or project entities, compare yourself with the multi-entity figure.

Data you don't control, stale division of interest (DOI) decks, and manual system handoffs push an upstream close toward the long end, as the calendar section below shows.

For cross-industry benchmarks by company size, see how long the month-end close should take, and compare your own close with the close benchmark checker.

An upstream checklist adds eight blocks to the normal close: production volume cutoff, revenue accrual and true-up, royalty and owner payables, joint interest billing, LOE accruals, AFE and capital review, DD&A with ARO accretion, and severance and ad valorem taxes. Each task needs an owner, a source document, a due day, and a separate reviewer.

The due days below match a 5-business-day close. BD1 is the first business day after month end.

If you want an Excel version, build it with these columns: task, workstream, owner, reviewer, source document, due day, GL accounts, and status, grouped by the workstreams above. The general month-end close checklist covers the cash, payables, payroll, and reporting tasks every company shares. The free month-end close checklist generator builds a starting file you can add these energy rows to.

Book revenue in the production month from estimated volumes times an estimated realized price, usually the index average less differentials and deducts, times your net revenue interest. Credit royalty and partner payables for their shares. When the statement arrives about 60 days later, book the difference as a prior period adjustment in the current month.

A revenue accrual records revenue you've earned before a purchaser statement or check confirms it. The general mechanics are in the guide to accrued revenue. In oil and gas, the estimate has three inputs:

1. 1VolumesUse run tickets, gas meter data, and well tests, and adjust for shut-ins and downtime
2. 2PriceUse the month's index average, such as WTI for oil or Henry Hub for gas, less location and quality differentials and gathering, processing, and transportation deducts
3. 3OwnershipApply the current DOI deck, so your share, partner shares, and royalty shares add up to 100%

Before you finalize the accrual, reconcile volumes. Tie field production to sold volumes on purchaser and pipeline statements, then to revenue by well and product. Investigate gaps above your review threshold, such as allocation errors, missing statements, or shut-in wells. Treat materiality as a trigger for review rather than a bright line, because a small recurring gap can point to a measurement or allocation problem. Volumes drive revenue, severance tax, and depletion, so an error here flows into all three.

The $675,000.00 splits into $442,968.75 for you (65.625%), $147,656.25 for partners (21.875%), and $84,375.00 for royalty owners (12.5%). Partner and royalty shares together are $232,031.25.

Texas severance tax on the same volumes is 4.6% × $603,000.00 = $27,738.00 for oil and 7.5% × $72,000.00 = $5,400.00 for gas, or $33,138.00 in total. Your 65.625% share is $21,746.81, and the partners' and royalty owners' share of $11,391.19 is withheld from their distributions.

In Texas, the first purchaser pays the oil production tax and deducts it from your proceeds, so the $27,738.00 of oil tax reduces the receivable. The gas tax is primarily paid by the producer unless a contract shifts it to the purchaser, so the $5,400.00 goes to severance tax payable. The purchaser's October oil tax is due November 25, and your October gas report is due December 20, or the next business day when the 20th falls on a weekend (December 21 in 2026). Other states set different rates, due dates, and filing rules.

With a 60-day lag, here's where each open month stands at the October close:

Two of the three open production months are estimates at every close, so the close is only as good as your price deck and volume cutoff. For the August true-up, say you accrued $430,000.00 of net revenue and the statement shows $421,500.00. Record the $8,500.00 shortfall as a prior period adjustment in October revenue, and don't reopen August. Assuming the shortfall is shared by decimal, the gross shortfall is $8,500.00 ÷ 65.625% = $12,952.38, and the other owners' 34.375% share is $4,452.38, so the entry is:

Severance tax on the shortfall trues up the same way. Booking the difference in the current month is correct when it's a change in estimate under ASC 250, as purchaser true-ups typically are. A true error in a closed period, such as a wrong decimal applied for months, follows your error-correction policy under ASC 250 instead.

Under ASC 606, you recognize oil and gas revenue when control passes to the purchaser, typically at the agreed delivery point in the production month. Whether gathering, processing, and transportation deducts reduce revenue or sit in expense depends on where control transfers and your principal-versus-agent analysis. Recognize only your NRI share as revenue when you sell for other owners.

There's no published benchmark for the typical gap between estimated and actual revenue. Track it yourself by comparing each month's accrual by well and purchaser with the statement when it arrives. If the variance keeps running in one direction, fix the price differential or volume estimate instead of accepting recurring prior period adjustments.

Joint interest billing is how the operator charges each non-operating partner its working-interest share of costs on a well. In the close it runs after LOE and capital are coded to wells and AFEs: apply the ownership deck, add COPAS overhead, move partners' shares to receivables, then issue JIB statements after the books close.

Under the COPAS 2005 accounting procedure, the operator bills non-operators on or before the last day of the month for the preceding month. Each party pays within 15 days of receipt, and late balances bear interest at Wall Street Journal prime plus 3% a year, compounded monthly, or the maximum lawful rate if lower. The COPAS 2022 Model Form moves to a 30-day payment period. Whichever version your signed JOA attaches as Exhibit C governs.

Your close looks different depending on which side of the JIB you're on:

The JIB cutoff and the close cutoff are different dates. The JIB cutoff is the last day costs can be coded into this month's JIB run, and costs coded after it go on the next JIB. The close still accrues those late costs in the right month.

The October JIB statement goes out on or before November 30. If the partner receives it on November 30, payment is due within 15 days, by December 15.

The partner can't wait for a statement that arrives in late November, so it accrues $50,000.00 from prior JIBs, AFEs, and known activity, then trues up when the JIB arrives. The operator builds its JIB from the closed month, so JIB timing never shortens the operator's close, but it does set the non-operator's estimate cycle.

If you're a non-operated working interest owner, apply this to every operator and purchaser: accrue expected JIBs and revenue by well, keep a received and not-received list, and true up in the current month when JIBs and checks arrive.

A JIB statement typically shows the property and well, the AFE number, the cost category and account, the gross amount, the partner's decimal interest, the partner's net share, COPAS overhead, prior balance, payments received, and the amount due.

To set up JIB in a mid-size E&P, start with master data: JOAs, ownership decks, COPAS overhead rates, and AFE numbers. Code every invoice to well, AFE, and account. Reconcile the JIB clearing account to zero each month, and review partner receivable aging before statements go out.

Accrue LOE from field tickets, prior-month run rates per well, and known activity like workovers, then reverse it on day one of the next month. If you operate, accrue the gross amount and move partners' shares to a JIB receivable. If you don't, accrue your net share of the expected operator JIB. True up when invoices arrive.

Lease operating expense is the operating cost, or opex, of an oil and gas well. It covers lifting costs such as pumpers, chemicals, saltwater disposal, electricity, compression, and repairs that keep a well producing without adding reserves. Example B shows both the operator's gross accrual and the non-operator's net accrual. The general method for unbilled costs is in the guide to accrued expenses.

Capital follows a different path. Code drilling, completion, and major workover costs to the AFE that approved them, not to LOE. Each month:

1. 1Accrue incurred costsUse daily drilling and completion reports to accrue work done but not invoiced
2. 2Compare to budgetTrack spend against each AFE and flag projects running over
3. 3Move completed wellsTransfer finished wells from wells in progress into producing properties
4. 4Flag suspended projectsSend suspended or abandoned projects for capitalization or impairment review

Intangible drilling costs (IDC), such as labor, fuel, drilling mud, and site preparation, are capitalized for book purposes under full cost. Under successful efforts, IDC on development wells is capitalized, while costs of exploratory wells that find no proved reserves are expensed. For federal income tax, many producers can elect to deduct IDC when incurred, subject to limits. At month end, code IDC to the AFE and accrue drilling invoices not yet received.

Monthly units-of-production depletion equals the depletable cost base divided by beginning-of-month reserves, times the month's production. Book it after final volumes are in. Accrete each ARO layer at its credit-adjusted risk-free rate. If you use full cost, run the SEC ceiling test at each quarterly reporting date, not monthly.

Depletion is the oil and gas version of depreciation: it spreads capitalized well costs over the reserves they produce.

The entry debits DD&A expense $525,000 and credits accumulated DD&A $525,000. Under successful efforts, development costs deplete over proved developed reserves and leasehold costs over total proved reserves. Under full cost, the whole pool depletes over total proved reserves, and SEC Rule 4-10(c)(3) sets the base: capitalized costs net of accumulated amortization, plus estimated future costs to develop proved reserves and estimated dismantlement and abandonment costs net of salvage. You may exclude the cost of unproved properties and major development projects until proved reserves are assigned. Don't count abandonment costs twice if they're already capitalized as ARO assets. Example C assumes future development and abandonment costs are zero and nothing is excluded. The rate holds between reserve reports unless something significant changes.

Full cost accounting capitalizes every cost of finding reserves, including dry holes, into one pool per country. Successful efforts expenses exploration costs that don't lead to proved reserves, such as geological and geophysical work and exploratory dry holes. The choice changes several close tasks:

The full cost ceiling, set in 17 CFR 210.4-10, is the present value of future net revenues from proved reserves discounted at 10%, plus unproved costs, less tax effects. Reserve prices are the unweighted average of the first-day-of-the-month price for each of the prior 12 months. Capitalized costs above the ceiling are charged to expense in that period.

Each month, accrete each asset retirement obligation (ARO) layer by its beginning liability times the credit-adjusted risk-free rate used when that layer was recorded, and classify the accretion as an operating expense, not interest. Add a new layer at the current rate for each well drilled in the month, depreciate the capitalized retirement cost, and charge plugging spend against the liability. For example, an illustrative $8,000,000 liability at a 6% annual rate accretes $8,000,000 × 6% ÷ 12 = $40,000 a month.

Accrue severance tax in the production month on the taxable value in your revenue accrual. In Texas, that's 4.6% of market value for oil, due the 25th of the next month, and 7.5% for gas, due the 20th of the second month. Accrue ad valorem tax monthly from the annual estimate, then true up to the bill. Other states differ.

Severance tax rides on the revenue accrual, as Example A shows. Ad valorem tax is an annual property tax on producing properties, so you spread the estimate evenly. For example, an illustrative $240,000 annual estimate means a $20,000 accrual each month, trued up when the bill arrives.

Royalties and owner revenue follow the sale. When you sell production for all owners, accrue the full sales value, credit your share to revenue, and credit royalty, overriding royalty, and partner shares to revenue distribution payables. Then:

• Withhold taxes by ownerDeduct each owner's share of severance tax from the distribution payable
• Reconcile payablesTie the distribution payable to the last distribution run plus new accruals
• Age suspenseReview owner suspense balances held for title issues, missing addresses, or minimum payment thresholds, and follow your state's unclaimed property rules
• Pay from actualsPay owners from the distribution run built on actual statements, not from estimates

Payment deadlines set when the distribution run has to land. In Texas, the first royalty payment is due 120 days after the end of the month of first sale, then, unless your lease or another written agreement sets a different schedule, 60 days after the end of the month of sale for oil and 90 days for gas. Royalties on federal leases are due at the end of the month following the month the oil and gas is produced and sold. Put both on your close calendar next to the purchaser statement dates.

Remeasure every open swap, collar, and basis swap at fair value using month-end forward curves, and record settlements for contracts that expired in the month. Many E&Ps don't designate derivatives for hedge accounting, so the full mark-to-market change hits earnings every close. Reconcile positions to counterparty statements before posting.

Diamondback Energy's 2020 Form 10-K, for example, says the company does not designate its derivatives for hedge accounting. If your company applies cash flow hedge accounting under ASC 815, changes in the hedge's fair value generally go through other comprehensive income until the hedged sale affects earnings. That also adds hedge documentation work each period.

A gas imbalance happens when you sell more or less gas than your ownership share of production, which leaves you overlifted or underlifted. At month end, reconcile pipeline and operator allocation statements to your entitlement and update the imbalance schedule by well. Under ASC 606, revenue generally follows actual sales, and you record a liability for overproduced positions you expect to settle in gas or cash, as your policy defines.

Typical oil and gas month-end entries are the revenue accrual and prior-period true-up, royalty and partner payables, severance and ad valorem accruals, the LOE accrual and its reversal, AFE capital accruals, JIB receivables and COPAS overhead, depletion, ARO accretion, derivative mark-to-market and settlements, gas imbalance adjustments, and intercompany entries.

For how each entry type is prepared and reviewed, see the guide to month-end journal entries. Companies with an operating entity that bills affiliated partnerships also need matched balances on both sides, covered in the guide to intercompany accounting.

A 5-business-day oil and gas close runs four workstreams in parallel. Lock volumes and accrue LOE on days 1–2, accrue revenue, royalties, and severance and mark hedges to market on day 3, and finish JIB and AFE review, DD&A, and ARO on day 4. Review, sign off, and lock on day 5, and send the management pack on day 6.

This illustrative calendar shows the order and the handoffs:

Two dependencies set the order. Depletion needs final volumes, so it can't start before the volume reconciliation is done, and mark-to-market needs month-end curves. For general calendar templates, see the month-end close calendar, and for the step-by-step order every close shares, see the month-end close process.

Late oil and gas closes tend to trace to four bottlenecks:

1. 1Late production dataVolumes arrive after cutoff, so revenue, taxes, and depletion all wait
2. 2Stale ownership decksA DOI change posted late forces revenue and JIB reruns
3. 3Missing statementsThe team waits for an operator or purchaser statement instead of estimating it
4. 4Manual handoffsReconciling the energy accounting system to spreadsheets and the general ledger by hand

Fix cutoff discipline first, then estimate anything missing by the cutoff day and true it up later. Lock the period at sign-off, as the guide to locking an accounting period explains, so true-ups land in the open month.

Track days to close, revenue accrual variance against actual statements, the number and dollar value of prior period adjustments, unreconciled items older than 90 days, owner suspense balances, JIB receivable aging, and the share of accounts reconciled and reviewed by the deadline. Review them monthly so estimate quality improves along with speed.

Calculate revenue accrual variance, the energy-specific measure, as the actual statement amount minus the accrual, by purchaser and month. For formulas, targets, and a free scorecard for the general close KPIs, see month-end close KPIs.

Midstream companies close on throughput and fees, utilities on metered usage and regulated rates, and renewable energy companies on metered megawatt-hours, PPAs, and renewable energy certificates. None of them books upstream depletion or JIB, but all three run on volume data that arrives after month end.

For utilities, close software has to handle high-volume reconciliation, fixed asset roll-forwards, and SOX-ready review rather than JIB or depletion. In renewable project finance, "financial close" also means the date a project's financing is signed. This guide covers the monthly accounting close, which picks up the new project entity, its debt, and its tax equity accounts once financing closes. In the monthly close for a renewable energy company, record REC revenue or inventory under your policy, since accounting for certificates varies by company. For midstream, apply the same estimate-then-true-up approach to meter allocations.

Upstream operators typically run a dedicated oil and gas accounting system such as Quorum (including the former OGsys), Enertia, IFS BOLO (formerly P2 BOLO), W Energy, or PakEnergy for revenue distribution, JIB, and division orders. Larger or diversified companies often use SAP or Oracle with industry add-ons. The close itself spans these systems, spreadsheets, banks, and field data.

The two layers do different work:

Production data usually flows from field capture or SCADA into a production accounting module, which allocates volumes to wells and feeds revenue accounting and the general ledger. The weak points are manual uploads and spreadsheet handoffs, which is why the volume reconciliation sits early in the calendar.

Mid-size operators often choose a dedicated oil and gas accounting system, because general ERPs need add-ons for JIB, revenue distribution, and division orders. Diversified companies with corporate entities often keep SAP, Oracle, or NetSuite at the top and feed it from the energy system. If you run NetSuite or QuickBooks Online for a small operator, keep the JIB and revenue math in a dedicated tool or add-on and post summarized entries to the ledger.

If you run SAP S/4HANA, Joint Venture Accounting does the partner split at period-end. The cutback allocates operated costs to partners by their equity share, equity adjustments rebalance costs when ownership changes, cash calls are reclassified against the costs they funded, and overhead is calculated. Run those steps before you reconcile the JIB receivables.

JIB is calculated inside these oil and gas accounting systems or their ERP add-ons. General close tools don't calculate JIB. They reconcile the JIB clearing and partner receivable accounts and track the JIB task inside the checklist.

Pick a close layer that works on top of your energy accounting system and ERP rather than a second oil and gas ERP. The close tool should run the checklist, reconcile every account, prepare entries with workpapers, and require reviewer approval before anything posts.

If you run Quorum or Enertia, keep the industry math there and use their own close features. You can also add a close platform above them for task tracking, balance sheet reconciliations, journal entry review, and audit evidence.

This section covers close software for energy and utility companies. Software for accruing your own company's utility bills is a different category.

Among general close vendors, BlackLine and Trintech publish dedicated energy pages, and FloQast publishes one energy case study. Numeric, HighRadius, and Ledge had no energy pages when we checked on November 10, 2026. The results below are what each vendor reports.

Ask each vendor to show a working connection to your energy system in the demo. BlackLine says it integrates with any ERP, but none of these vendors' energy pages names Enertia, Quorum, or IFS BOLO as a standard connector. Plan for a file or database extract from those systems. If your general ledger is NetSuite, SAP S/4HANA, or Oracle, a close tool with a native connector reads the ledger directly.

Use these requirements to compare month-end close software for energy companies:

For audit trail, check that every entry links to its source documents, such as purchaser statements, JIBs, and field tickets, and that the system keeps an append-only activity log your auditors can read. Account-level methods are in the guide to account reconciliation, and variance review is in the guide to flux analysis.

AI can automate much of the energy close today. AI agents can reconcile accounts line by line, prepare accruals and journal entries with workpapers, match purchaser statements, and flag variances. Accountants still own reserve inputs, impairment and ceiling-test judgments, ownership disputes, and policy calls, and a named reviewer should approve every entry before it posts. The guide to AI in the month-end close covers how to test whether it's working. To move work out of the close window, see the guide to a faster month-end close. To compare tools by the work they do, see the best month-end close software.

JIB, revenue distribution, and production accounting stay in your energy accounting system. Our Close Agent works on top of your ERP, reading from and posting approved entries to NetSuite, Oracle, SAP S/4HANA, Microsoft Dynamics 365, Business Central, and QuickBooks, and reading from Odoo. It runs the close checklist, reconciliations, and accruals, and nothing posts until a named approver signs off on the exact lines. It deploys in a dedicated AWS account we manage for you, in your own AWS account, or on-premises, so production and partner data can stay inside your network. To see how it fits your close, explore our Close Agent.