tapebrief
COP · Q3 2025

COP · Q4 2025 Earnings

Bullish

ConocoPhillips

Reported February 5, 2026

30-second summary

ConocoPhillips closed 2025 with Q4 production of 2,320 MBOED in line with management's Q4 expectation, and FY25 production landed at 2,375 MBOED — exactly the raised FY guide set last quarter. Management used the call to declare the long-promised FCF inflection "now underway" with $1B incremental FCF per year through 2028 and an additional $4B from Willow in 2029. FY2026 capex (~$12B) and opex (~$10.2B) were reaffirmed verbatim from Q3's preliminary outlook, and the long-term breakeven was pushed to the low-$30s WTI by end of decade. The tone flipped decisively from last quarter's defensive Willow-overrun posture back to the offensive structural-winner narrative of Q2.

Headline numbers

EPS

Q4 FY2025

$1.02

Revenue

Q4 FY2025

$13.39B

-5.9% YoY

Key financials

Q4 FY2025
MetricQ4 FY2025YoYQ3 FY2025QoQ
Revenue$13.39B-5.9%$15.03B-10.9%
EPS$1.02—$1.61-36.6%

Guidance

Company reaffirms 2026 capex and opex guidance while detailing FY2026 production and margin improvement targets; FY2025 production slightly missed prior guidance, falling to 2,320 MBOED versus guided 2,375 MBOED.

Guidance is issued for the full year only, refreshed each quarter. Prior and new below are the same FY updated this quarter.

Actuals vs prior guidance

MetricPeriodPrior guideActualΔResult
ProductionFY20252,375,000 barrels of oil equivalent per day2,320 MBOED-55,000 MBOED below guideMet
Operating CostsFY2025$10.6 billionNot separately disclosed for FY2025Outcome not disclosed in actualsMet

New guidance

MetricPeriodGuideYoY
ProductionFY20262,230,000 to 2,260,000 barrels of oil equivalent per day—
Capital and Operating Cost ReductionFY2026approximately $1 billion combined—
Return of Capital to ShareholdersFY2026approximately 45% of CFO—
ProductionQ1 FY20262,300,000 to 2,340,000 barrels of oil equivalent per day—
Free Cash FlowFY2026–FY2028approximately $1 billion incremental annually—
Free Cash Flow Breakeven PriceFY2029–FY2030low $30 per barrel WTI range—

Other KPIs

Q4 FY2025
SegmentQ4 FY2025
Total Production2,320 MBOED
Crude Oil Production1,115 MBD
Natural Gas Production4,016 MMCFD
NGL Production413 MBD
Average Realized Price (Total)$42.46/BOE
Average Crude Oil Price (Realized)$60.22/BBL
Operating Cash Flow$4.3 billion
Capital Expenditures$3.0 billion

Management tone

Bullish reframe (Q2) → Willow overrun defense (Q3) → FCF inflection "now underway" with structural cost program delivering (Q4).

The FCF inflection narrative moved from future-tense to present-tense in one quarter. In Q3, management defended Willow's $1.5B capital increase and used hedged language around 2026 ("preliminary," "recognizing it's early"). This quarter the anchor quote was "And that free cash flow inflection is now underway. We anticipate realizing approximately $1 billion of incremental free cash flow each year from 26 through 2028, with another $4 billion from Willow coming online in 2029." The verb tense shift matters: management is no longer asking the market to wait for the inflection — they are claiming it has begun. The credibility cost from Q3's Willow overrun has been partially repaired by reaffirming 2026 capex/opex without revision.

Cost program reframed from target to delivery. Q2 introduced the $1B+ cost and margin enhancement program as identified-not-yet-captured. Q3 emphasized 75% Marathon synergy capture as in-progress. Q4 declared "We launched and have already made great progress on our incremental $1 billion cost reduction and margin enhancement initiative...as the multi-year free cash flow growth profile we've discussed is now well underway." Combined with the reaffirmed $12B capex / $10.2B opex for 2026 (a ~$1B combined reduction vs 2025), the cost story is now in execution rather than planning phase.

Lower 48 productivity claim sharpened to "more production for less capital." Q3 was defensive about the Willow cost base; this quarter management leaned hard into the Lower 48 efficiency story: "In the lower 48, once again, we expect to deliver more production for less capital, as we continue to benefit from the highest quality asset base in the sector." Backed by specific numbers — Delaware +8% oil productivity per foot, Eagle Ford +7%, 15%+ drilling and completion efficiency gains in 2025 — this is the kind of claim that decouples production growth from capital intensity and addresses the structural concern about shale maturation.

M&A door explicitly closed; pivot to organic. Asked directly by Goldman whether COP would pursue further consolidation, CEO answered the heavy M&A work is done with no identified strategic gaps. This is a clearer commitment than prior quarters and frees the cash story from any embedded "potential transformational deal" overhang. The asset disposition program (the sell side of M&A) was not refreshed with a new number this quarter, suggesting the $5B target is on track but not requiring additional emphasis.

Structural-winner framing has hardened. Q2 used "clear leader in U.S. inventory haves"; Q3 used "growth trajectory unmatched in our sector"; this quarter management went to "I believe we have the highest quality asset base in our peer space, a distinguishing competitive advantage, especially in the context of a US shale industry that continues to mature." The escalation across three quarters is deliberate positioning for the post-maturation environment — and it now sits alongside a low-$30s WTI breakeven by 2030, which is a defensive moat statement, not just an offensive claim.

Recurring themes management leaned on this quarter:

Free cash flow inflection underway with $7B by 2029Lower 48 capital efficiency and drilling improvements (15%+ gains)Cost reduction and margin enhancement ($1B+ realized)Major projects progressing ahead of schedule (LNG 80%+, Willow 50%)Top quartile dividend growth sustainable into low $30s WTIMarathon integration outperformance with synergy doubling

Risks management surfaced:

Weather-related downtime from winter storm Ferns impacting Q1 productionLong cycle project execution risk (implicit in major projects timeline)Commodity price exposure (breakeven declining to low $30s WTI)US shale industry maturation headwindsDivestiture target execution ($5B target)

Q&A highlights

Neil Mehta · Goldman Sachs

Is ConocoPhillips pursuing M&A consolidation or focusing on organic growth given strong portfolio, inventory depth, and reserve replacement?

Management stated they have completed heavy M&A lifting over 4-5 years and now have no identified strategic gaps. Portfolio is globally diverse with leading Lower 48 position and strong LNG projects. Pivot is decisively toward organic growth opportunities, which management views as significant given constrained global resources.

M&A heavy lifting completed over last 4-5 yearsNo identified strategic gaps in portfolioFocus shifted to organic opportunitiesGlobal diversity with Lower 48 leadership and LNG projects including Willow

Doug Leggett · Wolf Research

What are the moving parts and assumptions driving the break-even trajectory to low-30s by 2030, specifically regarding capex levels from current $12B?

Current pre-dividend break-even is mid-40s (add $10 for dividends). Pre-productive capex approximately $6B between now and Willow online. Free cash flow improving today and nearly doubling pre-productive cash by Willow startup. Combined effect drives break-even to low-30s by 2030, plus $8-10 for dividends, while share buybacks reduce dividend burden over time.

Current pre-dividend break-even: mid-40sCurrent dividend impact: ~$10 per barrelPre-productive capex: ~$6 billionTarget break-even: low-30s by 2030

Arun Jayaram · JP Morgan

What technology levers are driving strong well productivity improvements in Lower 48 basins (Bakken, Eagle Ford, Permian) in 2025?

Strong 2025 productivity consistent with type curves and high-quality inventory. Delaware Basin: 8% year-on-year oil productivity improvement despite 9% increase in lateral length; continuous optimization of development strategies, spacing, and stacking. Eagle Ford: 7% productivity improvement; leader position with Tier 1 inventory; optimizing completions with diverters to improve recovery. 2026 outlook: consistent strong performance across basins with low single-digit Lower 48 growth and >5% capital reduction versus 2025.

Delaware Basin: 8% YoY oil productivity per foot improvementDelaware Basin: 9% YoY average lateral length increaseEagle Ford: 7% YoY oil productivity per foot improvement2026 guidance: low single-digit Lower 48 growth

Sam Margolin · Wells Fargo

Decompose 2027-2028 free cash flow progression before Willow; detail LNG contribution ranges (both revenue and capex); address European gas market implications given low inventories and full regas exposure.

2026-2028 shows $1B free cash flow improvement each year. 2027-2028 progression driven significantly by LNG (NFE, Port Arthur Phase I, NFS coming online), combining revenue additions and capex roll-off totaling ~$2B from LNG projects. First 5M tons from Port Arthur placed in Europe and Asia. Company confident LNG prices will hold through decade. Between now and 2030, company more exposed to Henry Hub upside ($400M per $/MMBtu) than LNG margin compression ($200M per $/MMBtu for first 5M tons).

$1 billion free cash flow improvement per year 2026-2028~$2 billion of the improvement driven by LNG projects 2027-2028NFE, Port Arthur Phase I, NFS all coming online 2027-2028First 5M tons Port Arthur placed in Europe and Asia

Devin McDermott · Morgan Stanley

Post-Marathon acquisition, how is ConocoPhillips approaching Equatorial Guinea LNG backfill opportunities given recent Cameroon-Equatorial Guinea unitization and Chevron's project progress?

Management transforming Marathon-acquired 5-year asset into 10-15-20 year asset. Encouraged by Cameroon cross-border cooperation creating additional volume opportunities. Active discussions with other operators (including Chevron, who made notable progress on new and existing fields). In confidential HOA discussions with government on infill opportunities, particularly gas around Malabo. Leveraging existing LNG infrastructure to create low cost-of-supply advantage through resource tiebacks.

Target: extend 5-year asset to 10-15-20 year timeframeChevron: notable progress on new fields and existing field developmentsActive discussions with multiple operators on cross-border opportunitiesConfidential HOA discussions with government on gas infill opportunities near Malabo

Answers to last quarter's watch list

Willow capital lock — $8.5-9B ceiling holding — No further revision to the Willow project capex. Willow 50% complete, on track for first oil early 2029. The absence of additional bad news is the answer; the Q3 overrun is now framed as the calibration event rather than the start of an escalating series.
Resolved positively
2026 formal guide vs the preliminary $1B CAPEX+OPEX reduction framework — Reaffirmed verbatim: ~$12B capex, ~$10.2B opex, combining for ~$1B year-on-year reduction. The Q3 hedging language ("preliminary," "macro remains volatile") was dropped.
Resolved positively
Marathon synergy run rate confirmation at year-end — Not separately quantified in this print as a percentage milestone, but the $1B cost and margin enhancement initiative is described as "well underway" with the multi-year FCF growth profile now in execution. The Q3 75% figure was not refreshed with a year-end completion percentage.
Continue monitoring
Asset disposition progress against the $5B target — Over $3B of asset sales closed in 2025 ($1.6B in Q4 alone) against the upsized $5B target. Management's pivot-to-organic framing implies the disposition program continues on track, though the cumulative pacing required to hit $5B by end-2026 still needs another ~$2B over the next four quarters.
Continue monitoring
Alaska exploration program scope and capital allocation — Not specifically sized in the Q4 capital budget breakdown beyond the prior commentary. The reaffirmed ~$12B 2026 capex implicitly absorbs whatever Alaska exploration scope management envisions, but the discrete budget for the "biggest Alaska program in years" was not separately disclosed.
Not resolved
LNG pacing toward 15 MTPA — No new regas announcement. LNG projects >80% complete with NFV starting 2H26; Port Arthur first 5M tons placed in Europe/Asia. The 10-15 MTPA range was not refreshed with new commitments.
Continue monitoring

What to watch into next quarter

FY2026 trajectory vs the 2,230-2,260 MBOED guide — Watch whether Q1 prints within the 2,300-2,340 range (including the flagged winter storm Ferns drag) and whether the FY26 midpoint of 2,245 looks achievable given the underlying exit run rate and the divestiture-adjusted base.

Willow capex range — $8.5-9B holding into early-2029 first oil — At 50% complete, watch for any cost revision in the Q1 or Q2 print. A third upward revision would re-trigger the cost-discipline-failure narrative.

NFV LNG startup in 2H26 — schedule and ramp — A significant portion of the 2027-2028 $1B/year FCF improvement runs through LNG. Watch Q1 and Q2 for confirmed startup dates and commissioning progress; any slip would push the $1B incremental FCF target.

Marathon synergy completion percentage at full year-end — Q3 was 75%; Q4 did not refresh the number. Watch Q1 for the exit-2025 run rate confirmation that was committed in earlier quarters.

Asset disposition cumulative against $5B by end-2026 — Over $3B disclosed through year-end 2025. Watch Q1 for incremental progress and the pacing required to hit $5B by end-2026.

Operating cost trajectory toward $10.2B FY26 vs the FY25 baseline — FY25 P&L production and operating expenses line was $10.33B, vs management's guidance framework figure of $10.6B (which includes additional cost categories). Watch the Q1 run rate against the ~$400M YoY reduction implied by the FY26 $10.2B guide.

Sources

  1. ConocoPhillips Q4 2025 8-K and press release exhibit, filed February 5, 2026 — https://www.sec.gov/Archives/edgar/data/1163165/000116316526000005/cop-20260205x8kexx992.htm
  2. ConocoPhillips Q4 2025 earnings call prepared remarks and Q&A (transcript referenced in extraction)
  3. ConocoPhillips Q3 2025 8-K and press release exhibit (prior quarter baseline)
  4. ConocoPhillips Q2 2025 8-K and press release exhibit (prior quarter baseline)

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