This post covers something different: the full arc of the 2026 Iran war oil price cycle, from the Q1 peak near $120 to the Q2 ceasefire trough near $73, and the specific impairment accounting problems that cycle creates for companies that acquired or capitalised assets at Q1 valuations and must now test them against Q2 balance sheet date conditions. This is not a generic impairment framework guide. It is a fact-specific analysis of a specific price cycle and its accounting consequences.
The confirmed facts from primary sources: Brent crude started 2026 near $63 per barrel. Following US and Israeli air strikes on Iran on February 28, prices surged more than 60% over March, with the IEA describing the conflict as the largest supply disruption in the history of the global oil market. Brent surpassed $100 per barrel on March 12 (EIA) and traded close to $120 per barrel at its peak (CNBC, IEA). By early April, the ceasefire announcement began bringing prices down. Physical crude spot prices were near $130 per barrel in early April per the IEA April Oil Market Report. By the June 17 MOU ceasefire, prices had fallen to the $73 range. The July 8 ceasefire collapse pushed prices back above $75 to $78.
For the June 30, 2026 balance sheet date, the operative fact is simple: oil prices at balance sheet date were approximately 37% to 40% below the Q1 peak. Assets acquired, developed, or impairment-tested in Q1 using oil price assumptions reflecting the $100-plus environment must now be assessed against conditions at June 30 that reflect a materially different price.
The Full 2026 Iran War Oil Price Timeline: $116 to $73 to $78 and What It Means for Accounting
The price cycle that drives the Q2 impairment analysis is confirmed from multiple primary sources:
Late February 2026: Brent at approximately $63 to $72 per barrel before the conflict began, reflecting the IEA's pre-war projection of a global supply surplus.
March 2026: The largest monthly oil price gain since records began in the 1980s, with Brent surging more than 60% over the month (World Bank Commodity Markets Outlook, April 2026). The price surpassed $100 on approximately March 12 (EIA Q1 2026 energy price review). CNBC and IEA reported Brent trading near $120 per barrel at its peak in March. The IEA's April Oil Market Report stated that North Sea Dated crude was trading around $130 per barrel at the time of the April report's writing, reflecting the physical spot premium above futures.
April 2026: Brent at approximately $92 per barrel in early April as the temporary ceasefire discussion and IEA emergency reserve releases provided partial relief.
June 17, 2026: The MOU ceasefire was signed. Prices fell toward the $73 per barrel range as the market priced in reduced Strait disruption risk.
June 30, 2026 (Q2 balance sheet date): Brent at approximately $73 per barrel. This is the operative price for ASC 360 recoverability tests, the ASC 350 goodwill fair value estimate, and the full cost ceiling test calculation reference date (though the ceiling test uses a 12-month trailing average, not the spot price).
July 8, 2026: Ceasefire collapse. Brent spiked approximately 6% to $75 to $78 per barrel (NBC News, Forbes). This is a subsequent event relative to the June 30 balance sheet.
The accounting significance: between March peak and June 30 balance sheet date, oil prices declined approximately 37% to 40%. Between the Q4 2025 pre-war level and June 30, prices at the balance sheet date are approximately 5% to 15% higher than where the year started. The Q1 peak is what creates the specific impairment problem: companies that based Q1 decisions on $100-plus oil must test those decisions against $73 oil at June 30.
Why the Q1 Peak and the Q2 Balance Sheet Date Create Two Different Impairment Problems
The price cycle creates two structurally distinct impairment problems that require separate analysis.
The first is a peak-to-trough problem for assets acquired or capitalised during Q1. If a company acquired oil and gas properties, a royalty interest, or another oil-price-sensitive asset in February or March 2026 based on valuations reflecting $80 to $100-plus oil, and if the acquisition price was supported by discounted cash flow analysis using those oil price assumptions, the June 30 balance sheet date presents those same assets at approximately $73 oil. The question is whether the carrying amount of those assets (the acquisition price plus any capitalised costs) is still recoverable under ASC 360, or whether goodwill associated with the acquisition is still supportable under ASC 350.
The second is a year-over-year problem for companies with existing oil-sensitive assets. A company that last performed its annual goodwill impairment test in Q4 2025 using oil price assumptions reflecting $65 to $70 oil may have a very different fair value estimate if the same test were performed at June 30, 2026 using $73 oil. The direction of change depends on whether the $73 June 30 price is above or below the Q4 2025 assumption. For most producers whose annual test assumed prices consistent with the pre-war environment, $73 oil is near the baseline, and the goodwill triggering event question focuses more on the uncertainty and volatility of the price environment than on the level.
These two problems require different primary standards, different timing of assessment, and different disclosure.
Problem 1 (ASC 360): If You Acquired or Capitalized Oil and Gas Assets in Q1 at $100+ Oil, Is Recoverability Still Supportable?
ASC 360-10, Property Plant and Equipment, governs impairment of long-lived assets. The standard requires an impairment test when events or changes in circumstances indicate that the carrying amount of a long-lived asset or asset group may not be recoverable.
The relevant triggering event for Q2 2026 is a significant adverse change in the business climate or a significant decline in the market price of a long-lived asset. For oil and gas properties or other oil-sensitive long-lived assets acquired in Q1 2026 at valuations reflecting $80 to $100-plus oil, the approximately 37% decline from Q1 peak to the June 30 balance sheet date is a significant adverse change in the price environment that triggers an ASC 360 recoverability assessment.
The ASC 360 recoverability test is a two-step process.
Step 1 is the recoverability test: compare the carrying amount of the asset or asset group to the sum of the undiscounted future cash flows expected from the use and eventual disposition of the asset. If the undiscounted cash flows exceed the carrying amount, the asset is recoverable and no further testing is required. If the undiscounted cash flows do not exceed the carrying amount, the asset is impaired and Step 2 is required.
Step 2 measures the impairment loss: the excess of the carrying amount over the fair value of the asset or asset group is the impairment loss. Fair value is measured under ASC 820 using the price that would be received to sell the asset in an orderly transaction between market participants.
For oil and gas properties specifically, the undiscounted cash flow test in Step 1 uses management's best estimate of the prices at which production will be sold over the life of the asset. Under the SEC's view and general practice, the long-term price assumption for the undiscounted cash flow test is not the current spot price but rather management's long-term price outlook. If management believes oil prices will recover to $80 to $90 over the long term, the undiscounted cash flow test may still show recoverability even at $73 current prices, because the undiscounted future cash flows reflect the long-term price outlook rather than the current price.
This distinction between the current price and the long-term price forecast is the most common source of judgment in the ASC 360 test for oil and gas assets. Companies must document why their long-term price assumption is reasonable, and auditors will scrutinise that assumption carefully given the scale of the Q1 to Q2 price movement.
What Is the ASC 360 Recoverability Test and How Do You Apply It at June 30?
The ASC 360 recoverability test at June 30, 2026 for oil-sensitive long-lived assets requires three specific inputs that must be documented in the impairment assessment file.
The carrying amount at June 30. For assets acquired in Q1, the carrying amount is the acquisition price plus any capitalised costs (acquisition costs, development costs) incurred through June 30, net of any depreciation, depletion, or amortisation recognised in Q1 and Q2.
The undiscounted future cash flows. The cash flow model must reflect management's best estimate of future production volumes, operating costs, and commodity prices over the remaining economic life of the asset. The commodity price assumption in the undiscounted cash flow test is not mandated by ASC 360 to use any specific price deck, but it must be supportable as management's genuine belief about future prices, consistent with the assumptions used in other financial statement presentations (for example, proved reserve disclosures).
The fair value of the asset group if Step 2 is reached. For oil and gas properties, fair value is typically estimated using a discounted cash flow (DCF) model that uses a risk-adjusted discount rate applied to proved and probable reserves, or comparable transaction multiples. The June 30 price environment and the price assumptions embedded in the DCF affect the calculated fair value.
The specific documentation challenge for Q1 acquisitions is establishing that the current carrying amount was supportable at the acquisition date and that subsequent conditions (the Q2 price decline) do not retroactively impair the carrying amount through ASC 805 purchase price allocation. The ASC 805 measurement period for a Q1 acquisition may extend into Q2, and purchase price adjustments made within the measurement period must reflect information that provides evidence about conditions that existed at the acquisition date, not information that became available after the acquisition date. The Q2 price decline is not a condition that existed at the Q1 acquisition date. It therefore does not affect the purchase price allocation but may trigger a separate ASC 360 impairment test as of June 30.
Problem 2 (ASC 350): If Oil Price Collapse From Near $120 to $73 Compressed a Reporting Unit's Estimated Fair Value, Is That a Goodwill Impairment Trigger?
For companies with goodwill allocated to oil-sensitive reporting units, the interim triggering event assessment at June 30, 2026, must address the oil price cycle directly.
The ASC 350-20-35-3C assessment requires the company to consider whether events and circumstances make it more likely than not that the carrying amount of the reporting unit exceeds its fair value. The oil price decline from Q1 peak to Q2 balance sheet date is directly relevant as both a cost factor indicator and an overall financial performance indicator.
However, the analysis is more nuanced than simply noting that oil prices fell. The relevant comparison for the goodwill triggering event assessment is the current conditions versus the conditions that were assumed when the goodwill was last tested (typically at the annual test date).
If the most recent annual goodwill impairment test was performed as of December 31, 2025 using oil price assumptions reflecting $65 to $70 per barrel (the pre-war environment), and if June 30, 2026 oil prices are approximately $73, the fair value estimate at June 30 may be similar to or slightly higher than at the December 31 annual test date. In that case, the triggering event assessment may not conclude that impairment is likely, despite the Q1 price peak.
The more concerning triggering event scenario is for companies that revised their fair value estimates during Q1 2026 in response to the price surge, either through an interim impairment test, a purchase price allocation, or a business valuation for other purposes, and that now face Q2 conditions approximately 37% below those revised Q1 estimates. For those companies, the deterioration from Q1 to Q2 is the relevant change to assess.
The ASC 350 goodwill blog from earlier in this cluster addressed the general framework. The Iran war-specific addition here is the magnitude: a 37% price decline from peak to June 30, in less than four months, is the kind of rapid change that compresses fair value estimates significantly for oil-weighted reporting units and may eliminate the headroom that allowed companies to avoid impairment at the prior annual test date.
What Is the "More Likely Than Not" Goodwill Triggering Event Standard for Oil Price Movements?
The more-likely-than-not standard under ASC 350-20-35-3C means a probability exceeding 50% that the carrying amount of the reporting unit exceeds its fair value. It does not require certainty. It does not require that a quantitative test produce an impairment. It requires that the combination of adverse conditions at the interim assessment date make that outcome more likely than not.
For the Q2 2026 triggering event assessment, the oil price-specific analysis requires the tax director and reporting unit management to answer four questions.
First: what was the headroom at the most recent annual test, meaning the excess of fair value over carrying amount at December 31, 2025? A reporting unit with 30% or more headroom is unlikely to have seen that headroom eliminated by a price decline to $73, which is near where oil started the year. A reporting unit with 5% to 10% headroom is much more vulnerable.
Second: has the reporting unit's actual Q2 2026 financial performance fallen below the projections used in the December 31, 2025 annual test? The oil price disruption affected not only producers but also refiners, petrochemical companies, airlines, and others in ways that may or may not match what the annual test projected.
Third: is the Q2 2026 fair value estimate, computed using current (June 30) oil price assumptions and current cash flow forecasts, materially different from the December 31, 2025 fair value estimate? This question requires at minimum a refreshed DCF model or comparison of key value drivers.
Fourth: does the combination of the first three factors make it more likely than not that the carrying amount exceeds the fair value? If yes, an interim quantitative goodwill impairment test is required.
Problem 3 (E&P Ceiling Test): The 12-Month SEC Average Price Mechanics With $120 in the Rear View
For oil and gas E&P companies using the full cost method, the ceiling test for Q2 2026 uses the 12-month trailing average of first-day-of-month prices through June 30, 2026. This ceiling test was addressed in detail in the prior blog in this cluster. The connection to the full price cycle analysis here is specific.
The 12-month average for Q2 2026 covers July 2025 through June 2026. The months from March through June 2026, which contain both the price surge toward $120 and the subsequent decline to $73, are all in the Q2 average window. The months from July through October 2025, which were at roughly $65 to $70 per barrel, drop out of the Q2 window. The net effect on the 12-month average depends on whether the high-price months (March, April, May 2026 first-day prices) more than offset the lower-price months dropping out.
The key point for the impairment testing synthesis: the ceiling test and the ASC 360 and ASC 350 tests use different prices. The ceiling test uses the 12-month trailing average (confirmed at $63.17 per barrel for Q1 per Talos Energy's EDGAR filing). The ASC 360 and ASC 350 tests use management's estimate of future prices, which may incorporate current market prices or longer-term price forecasts. Companies with both ceiling test exposure and ASC 360 exposure should be careful not to use inconsistent price assumptions across the different tests in the same set of financial statements.
What Did Talos Energy's $145M Q1 Impairment Tell You About What Q2 Looks Like?
Talos Energy's Q1 2026 Form 10-Q, filed with EDGAR, is the most specific primary source data point available on the ceiling test mechanics. Confirmed from the filing:
Ceiling test impairment in Q1 2026: $145.0 million.
SEC pricing used: $63.17 per barrel for oil, $3.97 per Mcf for natural gas, $18.50 per barrel for NGLs.
Q4 2025 impairment: $170.4 million.
The Talos Q1 impairment occurred at an SEC average price of $63.17 per barrel, meaning the Q1 trailing 12-month average did not reflect the March price surge at all (because the ceiling test for Q1 2026 uses prices through March 1, the first day of March, not through March 31). The March 1 first-day-of-month price, while elevated compared to January and February, was not near the late-March peak.
The Q2 ceiling test will incorporate the April 1, May 1, and June 1 first-day-of-month prices. These dates fall within the post-escalation, ceasefire negotiation period. If those first-of-month prices were in the $80 to $100 range (based on the confirmed price trajectory), the Q2 average will be higher than the Q1 average of $63.17, which would increase the ceiling and reduce impairment pressure compared to Q1.
However, companies whose cost pools significantly exceed the Q1 ceiling may still face Q2 impairments if the higher Q2 average is insufficient to bring the ceiling above the carrying amount.
The Talos Energy example also confirms the disclosure model: when ceiling test impairments occur, the 10-Q must name the specific SEC price, the specific impairment amount, and the qualitative warning about future impairment risk in subsequent quarters. Other E&P companies with similar full cost pools should use Talos's Q1 disclosure as a template for their Q2 disclosure structure.
Does the July 8 Rebound to $77/bbl Affect the June 30 Balance Sheet Tests?
No, for the ASC 360 and ASC 350 tests. Yes, as a subsequent event disclosure.
This point was addressed in the ceiling test blog but deserves emphasis in the impairment synthesis context. The ASC 360 recoverability test and the ASC 350 goodwill triggering event assessment are performed as of the balance sheet date: June 30, 2026. The price environment on that date is approximately $73 per barrel Brent. The July 8 rebound to $77 to $78 per barrel is a subsequent event that occurred after the balance sheet date.
Under ASC 855-10-25-1, subsequent events must be evaluated to determine whether they adjust the financial statements or are merely disclosed. An oil price rebound after the balance sheet date represents a change in market conditions that arose after June 30. It does not provide evidence about conditions that existed at June 30. It is a non-adjusting subsequent event.
The non-adjusting subsequent event does not change the June 30 impairment assessment results. An impairment charge that was appropriate at June 30 remains appropriate, even if prices have subsequently recovered. Conversely, a conclusion that no impairment trigger existed at June 30 is not affected by the subsequent price rebound.
The subsequent event does, however, change the forward-looking context of the Q2 disclosures. Companies that recorded impairments or found themselves near the impairment threshold at June 30 should disclose the post-quarter oil price movement as a subsequent event, confirming that prices have improved from the June 30 level and providing the expected impact on the Q3 ceiling test or future ASC 360 and ASC 350 assessments.
What Must Your Q2 2026 10-Q Disclose About Impairment Assessments?
The Q2 2026 10-Q impairment disclosures for companies with oil-sensitive assets must address three areas, each with specific content requirements.
For ASC 360 long-lived asset impairment: where an impairment charge was recorded, the disclosure must include the amount of the charge, the asset or asset group affected, the circumstance that gave rise to the charge (the oil price decline from the Q1 peak to the June 30 balance sheet date, with the specific price decline described), and the method used to estimate fair value. Where no impairment was recorded but the triggering event assessment was performed, the disclosure should describe the assessment and the basis for the conclusion that the carrying amount is recoverable.
For ASC 350 goodwill: where a triggering event was assessed and a quantitative interim test was performed, the disclosure must describe the test and its result. Where the assessment concluded no triggering event existed, the MD&A critical accounting estimate disclosure should describe the oil price decline, the reporting unit's exposure to oil prices, the headroom at the most recent annual test, and the sensitivity of the fair value estimate to oil price assumptions.
For E&P full cost ceiling test: the specific impairment amount, the SEC pricing used (the 12-month trailing average through June 30), the company's warning about future impairment risk if oil prices decline from current levels, and a comparison to prior quarter SEC pricing. The subsequent event disclosure should address the July 8 oil price recovery and its expected effect on the Q3 ceiling test.
Cross-consistency is required. The oil price assumptions used in the ASC 360 undiscounted cash flow test, the ASC 350 fair value estimate, and the full cost ceiling test must be consistent with each other and with the oil price assumptions used in the MD&A discussion of results and the known trends disclosure. A set of financial statements where the ASC 360 test uses a long-term price of $80 per barrel, the ASC 350 test uses $75, and the MD&A discusses oil price uncertainty at $73 contains internal inconsistencies that the auditor and SEC staff will identify.
Frequently Asked Questions
Does the decline from near $120/bbl in March to $73/bbl at June 30 trigger an impairment test?
Not automatically, but for assets that were acquired or capitalised in Q1 using valuations based on $100-plus oil, the decline creates an impairment trigger under ASC 360's significant adverse change in circumstances standard. For goodwill under ASC 350, the triggering event question depends on the magnitude of the decline relative to the headroom at the most recent annual test. For E&P companies using the full cost method, the ceiling test is required each quarter regardless.
What is the ASC 360 recoverability test for oil and gas assets?
ASC 360-10 requires a two-step impairment test for long-lived assets when events or changes in circumstances indicate the carrying amount may not be recoverable. Step 1 compares the carrying amount to the sum of undiscounted future cash flows expected from the asset. If undiscounted cash flows are insufficient, Step 2 measures the impairment as the excess of carrying amount over fair value. The undiscounted cash flow test uses management's long-term price estimates, not the current spot price alone.
What is the ASC 350 goodwill triggering event standard for oil price movements?
ASC 350-20-35-3C requires interim triggering event assessments at each reporting date. A triggering event exists when it is more likely than not (probability greater than 50%) that the carrying amount of a reporting unit exceeds its fair value. An oil price decline of 37% to 40% from Q1 peak to Q2 balance sheet date is a cost factor and macroeconomic indicator that must be assessed against the specific reporting unit's headroom at the most recent annual test.
Does the July 2026 oil price rebound affect the June 30 impairment assessment?
No. The ASC 360, ASC 350, and ceiling test assessments are all measured at the June 30, 2026 balance sheet date. The July 8 oil price rebound is a non-adjusting subsequent event under ASC 855. It does not change the June 30 impairment conclusions but must be disclosed as a subsequent event and should be addressed in the forward-looking MD&A discussion.
What must the Q2 2026 10-Q disclose about oil price-driven impairment assessments?
ASC 360 impairment charges require disclosure of the amount, the affected assets, the triggering circumstances, and the fair value method. ASC 350 goodwill assessments require disclosure where material, including the triggering event analysis, the headroom at the annual test, and the sensitivity of the fair value estimate to oil price assumptions. The ceiling test requires disclosure of the SEC pricing, the impairment amount, and a forward-looking warning about future impairment risk. All three tests must use consistent oil price assumptions.
Key Takeaways
- The 2026 Iran war created a specific oil price cycle: Brent started the year near $63 per barrel, surged near $120 at the March peak (confirmed by IEA April OMR, CNBC, EIA), and fell to approximately $73 at the June 30 balance sheet date following the June 17 MOU ceasefire. The July 8 ceasefire collapse pushed prices back to approximately $77 to $78.
- For Q2 balance sheet purposes, the operative price is approximately $73 at June 30. The Q1 peak is relevant for identifying triggering events; the June 30 price is what is used in the impairment calculations.
- ASC 360 recoverability tests are triggered for oil-sensitive long-lived assets acquired in Q1 at valuations reflecting $80 to $100-plus oil. The test uses management's long-term price forecast in the undiscounted cash flow model, not the current spot price alone.
- ASC 350 goodwill triggering event assessments must evaluate the oil price decline from the annual test price assumption to the June 30 level, against the headroom at the most recent annual test. Reporting units with narrow headroom at December 31, 2025 face the highest Q2 triggering event risk.
- E&P companies using the full cost method face a Q2 ceiling test using the 12-month trailing average of first-day-of-month prices. This average incorporates the post-conflict price surge months (April, May, June 2026 first-of-month prices), which may be higher than the Q1 average of $63.17 per barrel confirmed in Talos Energy's Q1 2026 EDGAR filing.
- The July 8 oil price rebound to $77 to $78 is a non-adjusting subsequent event under ASC 855. It does not change the June 30 impairment calculations but must be disclosed and addressed in the forward-looking MD&A.
- Cross-consistency is required across all three impairment tests and the MD&A. The oil price assumptions used in ASC 360, ASC 350, the ceiling test, and the MD&A discussion of results must be consistent and mutually supportable.
