ConocoPhillips Q1 2026: Marathon's Machine Runs, But Qatar's Shadow Looms

COP | NYSE | Source data: Q1 2026 earnings release (8-K filed April 30, 2026, accession 0001163165-26-000016), Q1 2025 10-Q, and supplemental financial information filed as Exhibit 99.2

Executive Summary

ConocoPhillips delivered Q1 2026 adjusted earnings of $2.3 billion, or $1.89 per share — down 10% from Q1 2025's $2.09 adjusted EPS but squarely within the range the company guided to after Marathon Oil's integration. This is the second full quarter with Marathon's Lower 48 assets absorbed, and the operational picture is clean: Lower 48 production held at 1,453 MBOED, cash from operations hit $5.4 billion (excluding working capital), and the company returned $2.0 billion to shareholders while spending $2.9 billion in capex. By COP's own framing, it's exactly what they said it would look like.

The headline miss from Q1 2025 is almost entirely macro, not operational. WTI averaged $71.93/bbl in Q1 2026 per industry price data in the supplemental — below Q1 2025's $71.42 benchmark quarter, but realized crude prices actually improved to $73.52/bbl for consolidated operations, up from $71.61/bbl a year ago. The real drag was natural gas: Lower 48 consolidated gas realizations collapsed to $1.19/MCF from $2.65/MCF in Q1 2025, a 55% deterioration that ran straight through to Lower 48 segment earnings and the consolidated $50.36/BOE average realization versus $53.34/BOE in the year-ago quarter.

The bigger story for Q2 and full-year 2026 is Qatar. ConocoPhillips has excluded Qatar from Q2 production guidance entirely due to "uncertainty surrounding the conflict in the Middle East," shaving approximately 20 MBOED off the annual production outlook. Combined with higher Surmont royalty rates at elevated oil prices, the company revised full-year production guidance down to 2.295-2.325 MMBOED. That's roughly 40-50 MBOED below what COP was running at Q1 2025's 2,389 MBOED pace.

CIR Analysis: The Qatar exclusion is the most significant overhang on COP right now. The company's Qatar operations — primarily Qatar LNG equity — sit within the Europe, Middle East and North Africa segment, which contributed $265 million in Q1 2026 earnings. That's manageable. But if the conflict timeline extends into Q3 or Q4, the full-year impact to production and earnings could be materially larger than the 20 MBOED annual adjustment currently embedded in guidance.

Production Performance

Lower 48 production held at 1,453 MBOED in Q1 2026, flat with Q4 2025 and essentially in line with the run rate COP established after the Marathon Oil close. Basin-level breakout from the supplemental:

• Delaware Basin: 698 MBOED
• Eagle Ford: 367 MBOED
• Midland Basin: 200 MBOED
• Bakken: 183 MBOED

Source: ConocoPhillips Q1 2026 earnings release (8-K Exhibit 99.1, April 30, 2026)

The Delaware at 698 MBOED is the largest single basin contributor and reflects the Marathon Oil integration — MRO had substantial Delaware (New Mexico) operations that became core COP acreage at the November 2024 close. Eagle Ford at 367 MBOED and Bakken at 183 MBOED are both Marathon-legacy positions; neither showed material growth quarter-over-quarter, though COP highlighted improved capital efficiency via longer laterals — more than doubling the percentage of 3-mile-plus lateral wells drilled compared to the prior year. That's not production upside today; it's cost-per-BOE and EUR improvement that flows through over 2026-2027.

Total company production of 2,309 MBOED was down 80 MBOED from Q1 2025's 2,389 MBOED. After adjusting for acquired and disposed assets, organic production declined just 14 MBOED or roughly 1% — a rounding error, but it's slightly negative. COP attributed this to downtime including the Middle East conflict impact on Qatar plus higher Surmont royalties.

CIR Analysis: The Lower 48 held its ground. There's no integration-related disruption visible in the basin numbers. COP guided that the Marathon assets would deliver operational continuity, and Q1 2026 supports that. The lateral length improvement is a meaningful signal that COP is drilling differently on these assets than Marathon was — longer wells, lower per-BOE cost structure. The full benefit of that capital efficiency shift will show up in 2026 and 2027 DD&A and finding costs, not Q1 2026 production.

Quarter-over-Quarter Production Snapshot:

Q1 2026: 2,309 MBOED | Q4 2025: 2,320 MBOED | Q1 2025: 2,389 MBOED

Lower 48: Q1 2026 1,453 | Q4 2025 1,439 | Q1 2025 1,462 MBOED

Source: ConocoPhillips Q1 2026 Supplemental (Exhibit 99.2)

Commodity Realizations

The realized price story in Q1 2026 is split: oil was good, gas was a problem.

Crude oil consolidated realizations came in at $73.52/bbl — higher than Q1 2025's $71.61/bbl and meaningfully above Q4 2025's $60.15/bbl. That reflects the Iran premium baked into Brent through Q1, with Brent dated averaging $80.61/bbl in COP's supplemental data versus $75.66/bbl in Q1 2025. COP's global crude portfolio is biased toward Brent-linked and regional crudes; the WTI-Brent spread of roughly $8-9/bbl in Q1 2026 benefited COP's international and Alaska barrels.

Natural gas realizations across the Lower 48 consolidated operations fell to $1.19/MCF — a severe deterioration from $2.65/MCF in Q1 2025. This is almost certainly a Permian gas story. The Lower 48 produces 2,067 MMCFD of consolidated natural gas, and a substantial portion of Permian/Delaware Basin associated gas trades at or near the Waha Hub, not Henry Hub.

Sidebar: The Waha Discount and COP's Lower 48 Gas Problem

Henry Hub averaged approximately $5.05/MMBtu in Q1 2026 on a first-of-month basis per COP's supplemental. That sounds healthy. But Waha — the Permian Basin natural gas pricing hub in West Texas — routinely trades at a significant discount to Henry Hub due to constrained takeaway capacity out of the basin. When COP's Lower 48 gas realizations are running at $1.19/MCF against a $5.05 Henry Hub reference, a large share of that gas is either priced at or near Waha (often negative during pipeline constraints) or hedged at below-market fixed prices. For COP's Q1 2026 Lower 48 segment, this realization compression versus the prior year was the primary earnings drag — not production volume, not lease operating costs.

Total average realized price across all segments was $50.36/BOE versus $53.34/BOE in Q1 2025, a $2.98/BOE decline. On 2,309 MBOED of production across 90 days, every dollar of per-BOE realization is worth roughly $208 million per quarter to pre-tax earnings.

Source: ConocoPhillips Q1 2026 Supplemental (Exhibit 99.2)

Financial Scorecard

Revenue and Earnings:

• Sales and other operating revenues: $15.8 billion (Q1 2026) vs. $16.5 billion (Q1 2025)
• Net income: $2.2 billion ($1.78/share basic) vs. $2.8 billion ($2.23/share) Q1 2025
• Adjusted earnings: $2.3 billion ($1.89/share) vs. $2.7 billion ($2.09/share) Q1 2025
• Effective tax rate: 35.1% (consolidated, Q1 2026)

Cash Flow:

• Cash from operations (CFO, ex-working capital): $5.4 billion
• Capital expenditures and investments: $2.9 billion
• Free cash flow (CFO less capex): approximately $2.5 billion
• Working capital change: -$1.1 billion (use of cash)
• Net cash from operating activities: $4.3 billion

Capital Returns:

• Share repurchases: $1.0 billion
• Ordinary dividends paid: $1.0 billion (Q0.84/share declared for Q2 2026, payable June 1)
• Total shareholder return: $2.0 billion, representing approximately 37% of Q1 CFO
• Full-year target: 45% of CFO returned to shareholders

Balance Sheet (March 31, 2026):

• Cash and short-term investments: $6.7 billion (cash $5.9B + short-term investments $486M)
• Long-term investments: $1.2 billion
• Long-term debt: $22.3 billion
• Total equity: $64.5 billion
• Shares outstanding (end of quarter): 1,218,294 thousand

Source: ConocoPhillips Q1 2026 Supplemental (Exhibit 99.2)

CIR Analysis: The cash generation is real. $5.4 billion CFO on $2.9 billion capex implies roughly $2.5 billion in free cash flow before dividends and buybacks. At $2.0 billion returned, COP is executing within its stated returns framework — not ahead of it, not behind. The 45% full-year CFO target is achievable at current commodity prices. The company ended the quarter with $6.7 billion in cash and short-term investments and $1.2 billion in long-term investments, which is a comfortable liquidity position given $22.3 billion in long-term debt. Debt service is not a near-term concern.

Marathon Oil Integration: Reading the Numbers

COP's Q1 2026 is the second full quarter since the Marathon Oil close in November 2024. Integration overhead is largely absent from the Q1 2026 special items — compared to $413 million in Lower 48 special items in 2025 (primarily transaction/integration and asset sale gains), the Q1 2026 special items net to -$141 million total company, almost entirely a Canada contingent liability charge. The Lower 48 shows zero special items in Q1 2026.

That matters because it confirms the integration overhead has cleared the income statement. What remains is the base business running the Marathon assets as part of COP's operating machine.

Lower 48 adjusted earnings of $1.403 billion in Q1 2026 compares to $1.697 billion in Q1 2025. Given the full Marathon integration, the Q1 2025 number should be considered a smaller asset base — Q1 2025 was before the full Marathon asset fold-in. On a comparable asset basis, the Lower 48 earnings decline is primarily the gas realization story, not integration-related underperformance.

The capital efficiency improvement on lateral lengths is noteworthy. COP disclosed it "more than doubled" the percentage of 3-mile-plus lateral wells on the Lower 48 in Q1 2026 versus the prior year. Marathon had developed a mixed lateral-length strategy; COP is standardizing on longer laterals where geology permits. This is the right call. Longer laterals reduce per-lateral drilling cost and typically improve EUR per well, translating to lower finding costs over time.

What Competitors Should Know

Permian gas takeaway is COP's operating problem and everyone else's too. COP's $1.19/MCF Lower 48 gas realization tells the story: if you're producing associated gas in the Delaware Basin and pricing at Waha, you're not getting paid for it. For operators without takeaway hedges or fixed-fee midstream arrangements, Q1 2026 Permian gas was essentially a disposal cost in certain weeks. COP is large enough to absorb this. Smaller Delaware Basin operators face a more acute realization drag.

Marathon integration sets the template for bolt-on M&A integration. COP completed a $17+ billion acquisition (Marathon Oil at $22.5B total enterprise value) and is running clean within two full quarters. Zero integration special items in Q1 2026. For Permian and Eagle Ford operators thinking about portfolio acquisitions, COP's execution speed is the reference.

Alaska Willow is 50% complete. This is a project-level signal for the North Slope services market. COP described a "successful Willow winter construction season" with 50% project completion. Willow is a multi-billion-dollar greenfield on the North Slope with peak production targeted above 180 MBOPD. The construction timeline means peak North Slope services demand is still ahead — likely 2026-2027.

LNG tolling agreement in Equatorial Guinea extends the life of an existing facility into the next decade. Not a volume mover, but it demonstrates COP's ability to utilize existing infrastructure efficiently and extract longevity from legacy international assets.

Outlook and Price Target Context

COP provided the following guidance for Q2 and full-year 2026:

Q2 2026 production guidance: 2.185-2.215 MMBOED (excludes Qatar) Full-year 2026 production guidance: 2.295-2.325 MMBOED Full-year 2026 capex guidance: $12.0-$12.5 billion (includes incremental Permian activity) Operating cost guidance: Unchanged from prior guidance Shareholder return target: 45% of CFO for full year

The Qatar exclusion from Q2 guidance is the most conservative element. COP quantified the annual production adjustment at 20 MBOED — a deliberate placeholder that acknowledges they simply don't know when or whether Qatar operations normalize. The supplemental shows Qatar and Middle East/Africa volumes within EMEA at 216 MBOED in Q1 2026. Not all of that is at risk, but if operations remain disrupted through Q2, the quarterly shortfall is real.

CIR Analysis: COP's $12-$12.5 billion full-year capex range is essentially flat with Q1 actuals at a $2.9 billion/quarter pace. The "incremental Permian activity" language suggests COP sees capital efficiency opportunities in the Delaware and Midland that weren't in the original budget. This is consistent with the lateral length improvement they're driving. The 45% CFO return target at $70-80 WTI is manageable; at current Brent levels above $96 per the April 30 morning brief, COP is likely running ahead of the return cadence needed to hit 45% for the full year.

The full-year guidance trim (from roughly 2.34-2.37 MMBOED implied to 2.295-2.325 MMBOED) reflects two discrete items: Qatar downtime and Surmont royalty rates. Neither is operational underperformance. The base business is performing.

CIR Verdict

ConocoPhillips delivered what it said it would. Marathon Oil integration is complete in operational terms, the Lower 48 is running at pace, cash returns are tracking, and the balance sheet is intact. The earnings decline from Q1 2025 is macro-driven — gas realizations in the Lower 48, specifically Permian/Waha pricing — not execution.

The two things to watch through 2026 are Qatar and gas realizations. Qatar is a black box with geopolitical timing that COP can't control. Gas realizations in the Lower 48 depend on Waha takeaway capacity improvement, specifically incremental Permian pipeline additions coming online. If Waha discounts narrow as new pipeline capacity fills, COP's gas realization drag reverses. If Permian gas remains oversupplied, the $1.19/MCF realization from Q1 2026 is the new normal.

CIR Analysis: At $96 WTI and with the Marathon integration fully digested, COP's operational machine is performing as designed. The stock discount to the peer group — if any exists after Q1 — would be Qatar-driven uncertainty, not fundamental underperformance. The Willow construction reaching 50% is a legitimate long-term production catalyst that the market may be underpricing at current prices. For the completions and services sector: COP's "incremental Permian activity" language and lateral length push are directionally positive for stage count and per-well service intensity.

Data Summary

Q1 2026 Production by Segment (MBOED)

• Total Company: 2,309
• Lower 48: 1,453 | (Delaware 698, Eagle Ford 367, Midland 200, Bakken 183)
• Alaska: 195
• Canada: 164
• Europe, Middle East and North Africa: 216
• Asia Pacific: 69
• Equity affiliates: 212

Q1 2026 Financial Summary ($M)

• Revenue: 15,761
• Net income: 2,183
• Adjusted earnings: 2,324
• CFO (ex-working capital): 5,400
• Capex and investments: 2,948
• Long-term debt: 22,262
• Cash + short-term investments: 6,363

Commodity Realizations Q1 2026 vs Q1 2025

• Crude oil (consolidated): $73.52/bbl (Q1 2026) vs $71.61/bbl (Q1 2025)
• NGL (consolidated): $20.06/bbl vs $24.86/bbl
• Natural gas, Lower 48 (consolidated): $1.19/MCF vs $2.65/MCF
• Total avg realized: $50.36/BOE vs $53.34/BOE

Macro Context

• WTI Q1 2026 quarterly avg (industry price per COP supplemental): $71.93/bbl
• Brent dated Q1 2026 avg (per supplemental): $80.61/bbl
• Henry Hub first-of-month Q1 2026: $5.05/MMBtu (per COP supplemental)

Source: ConocoPhillips Q1 2026 8-K and supplemental financial information (Exhibit 99.2), filed April 30, 2026

Crude Intelligence Report is an independent upstream oil and gas intelligence publication. The content in this article is for informational purposes only and does not constitute investment advice, financial advice, or a recommendation to buy or sell any security. Always conduct your own due diligence before making investment decisions. CIR and its contributors may hold positions in companies mentioned; any such positions will be disclosed when known. © 2026 Crude Intelligence Report. All rights reserved.

This article contains forward-looking statements and analytical opinions. Actual results may differ materially.