Is PV-10 the same as the standardised measure?

No. The standardised measure under ASC 932 is the after-tax figure GAAP requires in the 10-K supplemental oil and gas disclosures. PV-10 is its pre-tax sibling: same proved reserves, same SEC pricing, same 10% discount, but before future income taxes. PV-10 is a non-GAAP measure, so companies that quote it must reconcile it back to the standardised measure, and the reconciling item is the discounted value of future income taxes.

Where do I find a company's PV-10?

Start with the unaudited supplemental oil and gas disclosures near the back of the 10-K, which carry the standardised measure and the inputs behind it (future cash inflows, development costs, production costs, income taxes, the 10% discount). The pre-tax PV-10 itself usually appears in the year-end reserves press release or earnings release, with the required reconciliation to the standardised measure. Canadian issuers reporting under NI 51-101 publish before-tax and after-tax NPVs at several discount rates in their annual information form instead.

Why is an analyst NAV usually different from PV-10?

Five levers: pricing (NAV runs a forward planning deck, PV-10 uses the SEC 12-month historical average), reserve scope (NAV can include 2P or risked unproved value, PV-10 is proved only), corporate costs (NAV deducts G&A, PV-10 stops at the field gate), sustaining capital (NAV charges replacement capex to hold production flat, PV-10 produces the booked reserves and stops), and taxes (PV-10 is pre-tax; NAV applies an effective rate). Each lever is identifiable and quantifiable, which is what makes the bridge between the two numbers useful rather than just confusing.

PV-10 vs NAV: What the Standardised Measure Misses

Educational analysis for professional use. This guide is not investment advice or a recommendation to buy or sell any security, and it is not personalised.

Two Numbers That Look Alike and Aren’t

PV-10 and analyst NAV are both present values of reserve cash flows at a 10% discount rate, and that is where the resemblance ends. PV-10 is a regulatory disclosure built on rules a company cannot choose; NAV is a valuation built on assumptions an analyst must defend. Treating the disclosed figure as a ready-made valuation is one of the most common shortcuts in E&P screening, and it fails for identifiable reasons.

Every difference between the two numbers is rule-driven, so you can bridge from one to the other line by line. The disclosed PV-10 gives you a starting point every company has to compute the same way; the adjustments you layer on top are where your view differs from the SEC’s formula. This guide covers what PV-10 actually is, the five things it leaves out, and the reconciliation workflow that turns the gap into an edge.

What PV-10 Actually Is

PV-10 is the present value of estimated future revenues from proved reserves only, less future development, production and operating costs, discounted at 10%, before income taxes. The pricing is not a forecast: SEC rules (17 CFR 210.4-10) require the unweighted average of the first-day-of-the-month price over the trailing twelve months. Costs are held at year-end levels. There is no escalation, forward curve, or management overlay.

Its GAAP sibling is the standardised measure under ASC 932, disclosed in the unaudited supplemental oil and gas section of the 10-K. The standardised measure is the same calculation after future income taxes. PV-10 itself is non-GAAP, which is why companies that headline it in press releases must reconcile it to the standardised measure; the bridge item is the discounted tax burden.

Where to find it:

10-K supplemental oil and gas disclosures (usually near the back, unaudited): the standardised measure plus its components, future cash inflows, future development costs, future production costs, future income taxes, and the 10% discount line.
Year-end reserves or earnings press release: the pre-tax PV-10 figure, with the non-GAAP reconciliation.
Canadian issuers reporting under NI 51-101 disclose before-tax and after-tax NPVs at multiple discount rates instead, on forecast prices rather than the SEC trailing average. The reserves report guide covers that regime split in detail.

One scope note that trips people up: proved means proved developed plus proved undeveloped, and PUDs carry the five-year rule. Under 17 CFR 210.4-10, undeveloped locations must be scheduled for drilling within five years of booking unless specific circumstances justify a longer horizon. So PV-10 is not just conservative on certainty; it is constrained on timing. Inventory beyond the five-year window, however real, is simply not in the number.

The Five Things PV-10 Misses

The structural gaps line up neatly against what an analyst NAV does instead. The right-hand column shows the defaults used throughout these guides.

Lever	SEC PV-10 / standardised measure	Analyst NAV (typical defaults)
Pricing	12-month first-day-of-month historical average, costs frozen at year-end	Forward planning deck: WTI $70/bbl
Reserve scope	Proved only (1P), PUDs within the five-year rule	1P for a conservative case; 2P (proved plus probable) for Canadian and analyst base cases
Corporate costs	Field-level costs only; no corporate G&A	Corporate G&A deducted above the field level
Sustaining capital	Development costs for booked reserves, then the field runs off	Going-concern replacement capex to hold production flat, charged per barrel produced ($4-9/BOE across the worked fields here)
Taxes	PV-10 pre-tax; standardised measure after-tax on SEC pricing	25% blended US effective rate; Canadian assets on filed statutory plus royalty build

Two of these deserve more than a table row.

The pricing gap moves both ways. The SEC average is a trailing mirror. When prices have rallied, PV-10 lags below the market; after a crash, it can sit stubbornly above it for most of a year, flattering balance sheets just as lenders are re-cutting borrowing bases, the loan limits set against the value of a producer’s reserves. Set the two side by side and the direction is easy to read: when that trailing twelve-month average sits above the planning price you run, the pricing lever alone puts PV-10 above your NAV, before the other four levers pull it back down. Neither figure is anyone’s forecast. The SEC rule and your planning deck are both artificial; the useful work is naming which one you are using and why.

Blowdown versus going concern. PV-10 is in effect a blowdown calculation: produce the booked reserves, spend the booked development capital, stop. Real E&Ps don’t stop. A going-concern NAV charges the business for the capital required to replace what it produces, which is why a going-concern NAV carries a replacement capex line, and why F&D cost benchmarks matter to a NAV even though they appear nowhere in a PV-10.

Why the Gap Is the Edge

A disclosed PV-10 is the closest thing E&P investors get to a comparable, rules-based asset value, and the market broadly knows what it says. What you add is the bridge to your own NAV. If you can explain exactly why your NAV sits 30% below a company’s PV-10 (planning prices below the trailing average, G&A that the disclosure ignores, a tax charge the headline number excludes), you understand the asset better than someone quoting either figure in isolation.

Scale makes the discipline worthwhile. ExxonMobil booked 19.3 billion barrels of oil equivalent of proved reserves at the end of 2025, roughly an 11-year reserve life against production of about 4.7 million barrels of oil equivalent a day. ConocoPhillips carried 7.6 billion. Re-pricing reserve bases that size from the SEC average to a $70 planning deck moves tens of billions of dollars of present value. An integrated like ExxonMobil adds a second complication: PV-10 covers upstream only, so it can never speak to the downstream and chemicals segments that a sum-of-the-parts has to value separately.

The reconciliation workflow, starting from the 10-K disclosure:

Pull the standardised measure and its components from the supplemental disclosures; add back discounted future income taxes to get to pre-tax PV-10 if the company hasn’t disclosed it directly.
Re-run the production and cost profile at your planning deck instead of the SEC average. This is the single biggest swing item in most years.
Decide the reserve scope. Stay 1P for a conservative case; add 2P or risked unproved inventory where disclosure supports it (Canadian NI 51-101 filers make this much easier).
Convert blowdown to going concern: charge replacement capex so production holds flat rather than running off.
Deduct corporate G&A, apply your effective tax rate (our default: 25% blended for US assets), subtract net debt, divide by shares.

Each step is auditable. When your NAV and the disclosed PV-10 disagree, you can name the lever responsible, which is precisely what you cannot do with a multiple pulled from a comp sheet. For how the finished NAV pairs with cash-flow multiples in practice, see EV/DACF vs NAV.

The Gas-Weighting Trap

Comparing PV-10 per BOE across companies quietly assumes a barrel is a barrel. It isn’t. Reserves convert gas at 6:1, six thousand cubic feet (six Mcf) to one barrel of oil equivalent, which is an energy equivalence, not a value equivalence. At our planning deck a barrel of oil earns $70 of revenue while the six Mcf that count as its “equivalent” earn about $18 at $3.00/MMBtu Henry Hub. Same BOE in the denominator, roughly a quarter of the revenue in the numerator.

So a gas-weighted producer will show a structurally lower PV-10 per BOE than an oil-weighted one, and the difference says nothing about asset quality or operator skill. It is the commodity mix. Before screening on PV-10 per BOE, split the reserve base into liquids and gas (the 10-K reserve tables disclose the split) and compare like with like. The same trap applies to F&D cost per BOE and netbacks per BOE; any per-barrel metric inherits the 6:1 distortion.

PV-10 was never designed to be a valuation, and read as a disclosure with known blind spots it is one of the most useful numbers in the filing. The five-year PUD rule is the detail worth remembering: when a shale producer’s PUD bookings shrink, the market reads weakness, but sometimes it is just inventory sliding past a regulatory window that an NAV, on your own assumptions, is free to look beyond.