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The disclosure rules discussed below apply specifically to oil-and-gas companies reporting under U.S. Securities and Exchange Commission (SEC) rules. Other industries may use different reporting frameworks.
What does a quarterly production figure measure?
A production figure is a historical operating measure: it reports the quantity produced over a stated period. It is not automatically a measure of what the company sold, what it earned, or what it kept after operating expenses.
Before comparing two figures, establish their scope. For oil and gas, check:
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- Period and basis: Is the figure a quarterly total, a daily average, or another measure? Compare like with like.
- Product and unit: Identify whether the figure covers oil, natural gas, natural gas liquids (NGLs), or an aggregate such as barrels of oil equivalent (BOE). An aggregate does not make unlike products identical.
- Geography and ownership: Find the locations included and whether the reported quantity reflects the company’s net interest or another basis.
- Portfolio changes: Check for acquisitions, divestitures, joint ventures, or changes in capacity that affect what is included.
For U.S. oil-and-gas registrants, SEC Regulation S-K Item 1204 calls for production disclosure by final product sold and geographical area, as well as average sales prices and production costs. Its instructions generally define net production as the registrant’s interest after royalties and production due others; natural gas is reported on an “as sold” basis. The SEC’s oil-and-gas reporting guide summarizes the requirements, and the final rule and interpretation contains the rule text and instructions.
As Item 1204(a) puts it: “For each of the last three fiscal years disclose production, by final product sold, of oil, gas, and other products.” That annual disclosure requirement does not make any quarterly figure self-explanatory; check the company’s own filing for the period, units, and calculation basis.
Why can production rise while revenue falls—or the reverse?
Revenue depends on both quantity and realized price, along with product and sales mix. A company can produce more but receive a lower average price, or produce less while higher prices offset some or all of the volume decline. Production alone cannot establish the direction of revenue.
BSI Industries’ Form 10-Q for the quarter ended June 30, 2026, illustrates the distinction. The company reported 33,747 BOE produced, averaging 371 BOE per day, compared with 48,816 BOE, or 536 BOE per day, in the prior-year quarter. Despite lower production, oil and gas revenue increased by $0.1 million; BSI attributed the change primarily to a 41% increase in oil sales prices, partly offset by lower production volumes. These are figures for BSI and those specific periods, not industry averages. The company’s Form 10-Q provides the details.
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Why do production costs and product mix matter?
Compare production volume with both total production costs and the cost per comparable unit. A unit-cost change may reflect operating performance, but it can also result from a changed mix of products or properties. Confirm that the company calculates the metric consistently across periods before treating it as an efficiency trend.
In the same filing, BSI reported lease operating expense of $29.48 per BOE for the three months ended June 30, 2026, compared with $31.14 per BOE in the prior-year quarter. The company explained that its property mix had changed after divestitures. The lower cost per BOE therefore cannot, by itself, show that the retained operations became more efficient.
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How can asset sales or purchases change the trend?
A company’s total production can change because the portfolio changed, not just because its existing wells or facilities performed differently. When a filing provides enough detail, separate the effect of acquired or sold assets from the trend in retained operations. Also look for disclosed natural decline, downtime, or capacity changes.
BSI attributed its lower production quantities to divestitures in Wyoming and West Texas as well as natural decline in remaining assets. That explanation illustrates why a headline comparison of total production can blur two different developments: a smaller asset base and changes at assets the company still owns.
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Does a quarter’s production tell you how much remains?
No. Current output is not a reserve estimate and cannot establish reserve life, a depletion rate, or future production. Under SEC oil-and-gas definitions, proved reserves are estimated remaining quantities anticipated to be economically producible through development projects applied to known accumulations, subject to conditions that include rights, market access, permits, and financing. Reserve estimates require their own disclosures and assumptions.
Those estimates can also be sensitive to commodity prices. Permian Resources’ 2025 Form 10-K reported that a 10% increase or decrease in the crude-oil and natural-gas prices used in its December 31, 2025 reserve estimates was associated with a 45.5 MMBoe increase (4.1%) or a 69.5 MMBoe decrease (6.2%) in proved reserve quantities, respectively. Its reported pre-tax PV-10 sensitivity was plus or minus $2.2 billion (24% and 23%, respectively). These are company-specific sensitivities to stated price changes, not general rules or forecasts. See the company’s 2025 Form 10-K.
What to check when comparing periods or companies
- Match the periods and units. Compare the same length of period and the same measure, such as quarterly totals with quarterly totals or daily averages with daily averages.
- Break out products and locations. Check whether shifts in product or geographic mix explain part of the change.
- Confirm the reporting interest. Review whether quantities are gross or net and how royalties or production due others are treated.
- Account for portfolio changes. Identify asset purchases, divestitures, joint ventures, or capacity additions that alter the comparison.
- Read price and revenue disclosures alongside volume. Compare realized sales prices and revenue to see how quantity and price moved together or in opposite directions.
- Check total and unit costs. Look for changes in calculation basis or asset mix before interpreting a cost-per-unit movement as better or worse operations.
- Read the explanation and longer-term disclosures. Management’s discussion can explain the period’s movement; reserves, development spending, debt and liquidity, infrastructure constraints, and guidance add context but involve assumptions and risks.
The SEC’s oil-and-gas reporting categories help frame comparisons among U.S. registrants, but company-specific qualifications must come from each company’s filings. Do not treat a volume change as a conclusion about performance until the scope, price, cost, and portfolio context are clear.
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