Permian Gas Is Back Above Zero and the Dividend Is Up 11%, but the Share Price Still Assumes the War Continues

Results vs. Consensus

ConocoPhillips reported third-quarter 2026 results before the open on November 5, filed its 10-Q the same morning and held its call at noon Eastern. It was the first call for Andy O'Brien as president and chief executive and for Konnie Haynes-Welsh as chief financial officer. The quarter beat on earnings and revenue, grew cash from operations 33.7% year over year, raised the dividend by 11% and stepped up the buyback for a second consecutive quarter. The market treated it as a footnote to a week dominated by the Middle East and by a collapse in technology stocks.

Q3 2026 Scorecard

Consensus basis note: four independent marks for adjusted EPS were collected and they span $2.97 to $3.06. The beat is +6.9% at the top of that range and +10.1% at the bottom. The company reports two top lines, sales and other operating revenues of $19,435M and total revenues and other income of $20,057M. Vendor revenue marks of $18.38B to $18.92B appear to be struck against the broader line, and the print clears them on either basis. Every actual and prior-period comparative below comes from the 8-K income statement and supplemental tables, not from a data vendor's row or a figure quoted on the call.

Year-over-Year Comparison

Sequential Comparison

Sequentially the quarter is close to flat, and that flatness hides two large moves going in opposite directions. Dated Brent averaged $97.00 against $104.52 in the second quarter, so crude realizations fell by roughly a tenth. Natural gas went the other way: the consolidated gas realization tripled to $4.82/MCF as the Lower 48 stream recovered and Norway's gas sold for $21.14. Volumes rose 2.4% as Qatar partly restarted and the Lower 48 grew.

Revenue

Total revenues and other income of $20,057M rose 29.2% on a production base that shrank 4.0%, because the realized price per barrel of oil equivalent rose 32.2% to $61.40. The marketing spread, sales less purchased commodities, rose 30.9% to $12,012M, in line with the top line. Equity in earnings of affiliates rose 87.4% sequentially to $448M, the largest relative move among the major revenue lines. Two things drove it. Qatar partly restarted, lifting equity-affiliate production to 179 MBOED from 147. And Australia Pacific LNG's oil-linked contracts priced off a Japan Crude Cocktail of $111.24, which carries the second quarter's crude spike with a lag. The 10-Q attributes $153M of Asia Pacific's year-over-year increase to higher equity-affiliate earnings on higher LNG marker prices and volumes.

The revenue beat against consensus is therefore a price beat with a timing component. The crude benchmarks fell 7% to 8% sequentially, and JCC rose 65.7%. That lag should run the other way in the fourth quarter, when JCC reflects the third quarter's lower crude.

Costs and Margins

Costs were the cleanest part of the quarter, which reverses the second quarter's pattern. Production and operating expenses of $2,440M fell 7.3% year over year and were flat sequentially on 2.4% more volume. Per barrel of oil equivalent that is $11.52, down 3.0% from $11.88 in the second quarter and 3.4% below the $11.93 of a year ago. The 10-Q attributes $78M of lower Lower 48 operating expense to efficiencies. Selling, general and administrative expense fell 19.2% to $219M.

Depletion eased as well, though the explanation matters more than the number. Company DD&A of $3,005M was $14.19 per barrel of oil equivalent of total production, up 7.3% year over year but down 2.7% sequentially, and the year-over-year increase decelerated from 11.8% in the second quarter. Part of that is a denominator effect: Qatar's partial return adds equity-affiliate barrels that carry no consolidated DD&A. On consolidated production alone the rate was $15.39, up 5.5% year over year against 9.2% in the second quarter. In the Lower 48 the unit charge was $15.44, up 4.4% against 9.3% last quarter. The 10-Q gives the mechanism: higher rates "due to higher net book values from the finalized allocations of our Marathon Oil purchase price to specific assets and lower proved developed reserves as of December 31, 2025." That is a different cause from the one we proposed in August, when we linked rising depletion to longer laterals and heavier completions.

Interest and debt expense fell 36.3% to $142M. Incurred interest fell 13.5% to $281M on flat debt, and capitalized interest rose to $139M, which is 49.5% of the incurred figure against 31.4% a year ago. As we noted last quarter, the capitalized share is a legitimate construction-period treatment for Willow and Port Arthur that reverses when those projects start up.

Earnings and Cash

GAAP EPS of $3.34 exceeded adjusted EPS by $0.07 because special items netted to a positive $83M. A $126M reversal of a tax reserve in Corporate did most of it, partly offset by $33M after tax of pending claims in the Lower 48 and $23M of transaction costs. Canada's run of Surmont-related charges, which reached $180M after tax in the first half, fell to $8M of transaction costs this quarter.

Cash provided by operating activities was $7,195M, with a working capital release of only $23M, so the non-GAAP CFO of $7,172M is essentially the GAAP figure. Free cash flow was $4,039M after $3,133M of capital. Distributions of $3,408M were covered 1.19 times by GAAP free cash flow, a thinner cover than the second quarter's 1.46 times because distributions rose 12.7% while GAAP free cash flow fell 7.9%. The $1,566M of disposition proceeds landed in investing cash flow as expected, and the company split the surplus between cash and short-term investments, which rose to $2,164M from $1,118M.

Price Realizations and the Benchmark Disconnect

Last quarter crude and gas split violently in opposite directions. This quarter they did it again, with the signs reversed, and the Lower 48 segment total barely moved.

The Lower 48 Gas Price Comes Back Above Zero

Lower 48 natural gas realized $2.05 per MCF, against negative $1.44 in the second quarter and $1.62 a year ago. At 69.3% of Henry Hub it is the best capture rate since the first quarter of 2025. The variable we have called the analytical center of this name for two quarters went from the largest adverse item in the income statement to a modest year-over-year tailwind in ninety days.

The scale, measured the same way as last quarter. Lower 48 gas volumes were 2,238 MMCFD, which is 205.9 million MCF over the 92-day quarter. At $2.05 that volume produced roughly $422M of revenue, against negative $279M on the second quarter's smaller volume. At constant third-quarter volumes the sequential swing is $719M pre-tax. Against the year-ago realization it is a gain of about $89M. The 10-Q puts a company number on what came before: nine-month Lower 48 earnings absorbed "lower gas prices of $611 million driven by lower gas realizations".

And the recovery is invisible in the segment total for the same reason the collapse was. Lower 48 crude volumes of 738 MBD realized $85.63 against $96.24, which at third-quarter volumes is about $720M of lower revenue from price alone. The gas recovery and the crude retreat cancelled almost to the dollar. In the second quarter a $104 Brent hid a negative gas price. In the third, a retreating Brent hid its recovery.

The only forward-looking company language on regional pricing sits in the 10-Q's business environment section.

"U.S. Henry Hub prices were slightly lower relative to the same period of 2025 as rising domestic production contributed to a well-supplied market. The risk of volatility in regional markers remains throughout 2026."
— ConocoPhillips third-quarter 2026 Form 10-Q

Assessment: This is the most important single number in the quarter for our thesis and it moved decisively in the right direction. New Permian takeaway capacity was the obvious candidate cause and the realization is consistent with it. We have argued for two quarters that a model carrying Lower 48 gas at a normalized share of Henry Hub overstated the segment. That argument now runs the other way for the third quarter: a model still carrying it near zero understates it. What has not changed is that the company has given no forward view. The recovery is a market outcome reported in a supplemental table, not a disclosed expectation, and the only company sentence on regional pricing is a risk warning. We move the bear point down a notch and keep it open.

Crude Gives Back Its Premium

Lower 48 crude captured 99.8% of WTI, down from 103.7% in the second quarter. The WTI-to-Brent spread barely changed, $11.21 against $11.73, so last quarter's above-benchmark capture was not purely the spread effect we attributed it to in August. Consolidated realized crude fell 10.6% against a 7.2% fall in dated Brent. Alaska realized $96.52 and Norway $100.71, both still close to their benchmark.

Over the year, Canada again shows how this portfolio hedges itself against the shareholder. Bitumen realized $57.58, up 38.5% year over year, while bitumen volumes fell 22.8% to 95 MBD. The 10-Q explains the decline as higher variable royalties at Surmont, which run on a sliding scale from 25% to 40% of gross revenue net of allowable deductions after payout, indexed to WTI in Canadian dollars, plus normal field decline. Sequentially, volumes fell 17.4% while the price slipped 5.6%, which royalties alone do not explain, and the filing does not break that move out.

Assessment: The crude realization fell more than the benchmark this quarter, and the reason for last quarter's 103.7% capture is less clear than we thought. For modelling, 98% to 100% of WTI is the defensible range. The bigger point is directional. Every crude number in this table was struck while the conflict premium was still in the benchmark. Brent futures closed at $94.62 the day before the print, below the third quarter's $97.00 dated average, after peace talks took more than $18 off their late-October level.

Segment Performance

Segment production components may not sum exactly to consolidated operations because of rounding in the reported figures. On a pro forma underlying basis, which strips out closed dispositions, production fell 1.7% year over year to 2,295 MBOED from 2,334.

Lower 48

Production of 1,517 MBOED was the segment's highest of the year, and it came after the July sale of non-core assets that produced about 24 MBOED in 2025. The Delaware produced 757 MBOED and the Midland 197, a combined Permian 954 MBOED that is 3.5% above the 922 MBOED record set in the second quarter. The Eagle Ford contributed 369 MBOED and the Bakken 191. Segment capital rose 3.6% sequentially to $1,699M, the largest Lower 48 quarter of the year.

"And 1 of our crews pumped 23 hours per day in August, and that was a record for us as well as the vendor."
— Nicholas Olds, EVP Lower 48 and Global HSE

The completion detail was specific: pumping hours up 15% on the 2025 average and a 20% improvement in stimulated footage per day, from simul-frac on longer laterals. The surfactant programme now has about a year and a half of data on several groups of wells and is still showing up to 20% oil-productivity uplift. It will be applied more widely in 2027 at what management called a measured pace. On the secondary Permian benches the framing was deliberately restrained.

"So as the secondary zones that you just mentioned, like the Woodford and the Barnett, you know, we look at that as really as upside on top of that inventory depth. Really not a replacement for it."
— Nicholas Olds, EVP Lower 48 and Global HSE

Adjusted earnings fell 3.5% to $2,494M. The composition is the mirror image of the second quarter: gas added about $719M of pre-tax revenue sequentially at constant volumes and crude took away about $720M. Year over year, the 10-Q attributes $1,822M of higher sales revenue to realized prices, $78M of lower operating expense to efficiencies, $94M of lower earnings to volumes and $60M of higher DD&A to the Marathon purchase-price allocation and lower proved developed reserves.

Assessment: The operating case for this segment strengthened again. A Permian record after a disposal, a completion record set with a vendor, and a 2027 growth outlook "driven by the Lower 48" are consistent with the inventory-depth pillar we have scored as on track since initiation. The financial character has also improved: for the first time in our coverage the segment's gas stream is contributing rather than subtracting. The rising capital line is the one thing to watch. Lower 48 spend is up 8.1% year over year on a production base that is roughly flat, and management guided company capital higher again in the fourth quarter.

Alaska

Adjusted earnings fell 19.0% sequentially to $423M as Alaskan crude realized $96.52 against $108.49, and rose 171% year over year. Production of 185 MBOED was up 1.6% on a year ago on improved base performance and new wells, including first production from the Coyote expansion pad in August. Capital rose 24.3% year over year to $936M on Willow construction.

"we do start drilling next year, and that is important to build a production ready inventory so that we can have a strong ramp up, in the early part of 2029 and across that full year."
— Kirk Johnson, EVP Global Operations and Technical Functions

The exploration programme gets a second season: roughly four more wells and more seismic this winter after a first season described as positive enough to plan for more resource into Willow. Federal permits for the programme are in hand.

Assessment: Alaska is executing to the schedule laid out a year ago and the forward disclosures moved from hope to plan. Drilling in 2027 to build a pre-start inventory is the right sequencing for a strong 2029 ramp. The segment's inclusive tax rate of 41.5% remains the reminder that an Alaskan dollar of pre-tax income is worth less than a Lower 48 dollar, which is part of why the Willow economics depend on cost of supply rather than headline volume.

Canada

Adjusted earnings halved sequentially to $187M. Production fell to 147 MBOED, with bitumen down 17.4% sequentially to 95 MBD, partly offset by Montney gas and liquids. The segment's run of pending-claims charges stopped, leaving only $8M of transaction costs as a special item.

"And those incentives range from accelerated depreciation to support on both capital and cost."
— Kirk Johnson, EVP Global Operations and Technical Functions

The forward story is better than the quarter. Surmont Pad 104W-B reached first production in September, ahead of schedule and under budget, and the prior pad is outperforming. The company is negotiating, with the other Oil Sands Alliance members, the fiscal incentives in a trilateral memorandum with the federal and provincial governments that has not yet been formalized.

Assessment: Canada is the clearest example of a portfolio where high prices and high volumes do not coexist: the royalty scale takes volume as price rises. The new pad should lift 2027 volumes, as management said. The fiscal memorandum is the more consequential item, because accelerated depreciation and capital support would make a Surmont expansion competitive inside the portfolio. That is also the kind of new growth capital that the post-2029 narrative makes room for, and it belongs on the list we will grade against the February budget.

Europe, Middle East and North Africa

Adjusted earnings rose 4.6% sequentially and 10.4% year over year to $362M on production down 6.2% year over year to 213 MBOED. Norway's gas realized $21.14/MCF, the highest in the portfolio, and Libya held at 68 MBOED. The adjusted effective tax rate rose again, to 78.3% from 74.9%, and the 10-Q attributes $109M of lower year-over-year earnings to "tax impacts" from a shift in the mix of income among taxing jurisdictions. Lower equity-affiliate earnings, mainly on Qatar volumes, cost a further $22M year over year. Capital fell 26.6% to $215M.

This is also the segment where the portfolio is moving. In October the company notified employees, partners and regulators that it is evaluating a sale of its Norway business and the Teesside asset after an unsolicited offer. Norway is about 5% of 2025 production. The Kirkuk acquisition, at a $0.4B purchase price of which $0.2B is deferred for up to three years, is expected to close by year end with a July 1 effective date.

Assessment: A 78.3% tax rate means this segment keeps about a quarter as much of each pre-tax dollar as the Lower 48 does. A Norway sale at the right price would therefore be cleaner for consolidated returns than its production share suggests. Selling high-tax, mature OECD barrels while buying Middle East redevelopment barrels with cost recovery is coherent portfolio logic. It also shifts the country-risk mix of the segment further toward the jurisdictions where disclosed contract terms are not the whole of the risk.

Asia Pacific

The quarter's best segment sequentially. Adjusted earnings rose 35.7% sequentially and 70.9% year over year to $528M on production down 10.3% to 61 MBOED, mostly in Malaysia, which the 10-Q attributes to normal field decline. The driver was Australia Pacific LNG: higher equity-affiliate earnings of $153M year over year on higher LNG marker prices and volumes. Because equity-affiliate income is recorded after tax, the segment's adjusted tax rate fell to 11.2%.

Assessment: This is the lagged oil-linked LNG contract doing what it does. JCC averaged $111.24 in the third quarter because it trails the second quarter's crude spike. The third quarter's crude averaged less than the second's, so the lag should run against the segment in the fourth quarter. Treat the third quarter's $528M as a peak, not a run rate.

Corporate and Other

The adjusted loss narrowed to $76M from $268M in the second quarter and $306M a year ago. After-tax net interest expense fell to $34M on higher interest income and lower incurred interest, and corporate G&A fell to $83M. The larger contributor was the tax line: an adjusted benefit of $139M on a $215M pre-tax loss. Year to date the adjusted loss is $484M against the roughly $0.9B full-year figure guided at the second quarter. The third-quarter release did not restate that guide.

Assessment: Two of this year's three quarters, the first and the third, have drawn a large adjusted tax benefit from the corporate segment. The first quarter's corporate line was one of three items in our quality-of-beat critique at initiation, although we attributed it then to interest and G&A rather than tax. This one is smaller relative to the operating result and the beat survives without it, but it is not an operating item. A guided full-year loss of about $0.9B would imply a fourth-quarter loss of around $416M, which is far above any run rate this year. Either the guide is conservative or something is coming, and the company did not say which.

Cash, Capital Return and the Balance Sheet

The quarter's distribution of 47.5% of CFO is the first above the 45% annual objective this year, and it lifts the year-to-date figure to 42.9%. Getting to 45% for the year requires fourth-quarter distributions of about $3.6B if fourth-quarter CFO matches the third quarter's $7,172M. That is 50.7% of the quarter's CFO, and after roughly $1.1B of dividends at the new $0.93 rate it implies about $2.5B of repurchases. Second-half buybacks would then total about $4.9B against the roughly $4.3B we estimated in August, because CFO came in above the first-half run rate we assumed.

The monthly detail in the 10-Q is worth reading. The company bought 5.9 million shares in July at $112.09, 5.4 million in August at $125.96 and 8.0 million in September at $132.39, a quarterly average of $124.39 against an average closing price of $123.91. September, the month with the highest prices, took 41% of the quarter's shares. That is not the counter-cyclical pattern the company describes, though the annual-percentage framework makes some of it mechanical: the money has to be spent within the year. Shares outstanding fell 1.6% to 1,182.3 million. The balance sheet ended with $10.4B of cash and short-term investments plus $1.1B of liquid long-term investments, against $23.3B of debt, and management put net debt at 0.5 times CFO.

Key Topics & Management Commentary

Overall Management Tone: Prepared, consistent and noticeably longer-horizon than the previous team's calls. Management treated the quarter as a proof point and spent its time on what comes after 2029, with an unusual early look at 2027 that reads as a deliberate attempt to own the narrative before the February budget. Answers were confident on Willow, LNG and capital return. They were vaguer on the cost of new growth, on country risk in the Middle East, and on the Lower 48 gas price, which again went unmentioned.

1. A First Call Built on Continuity

O'Brien opened by restating the five capital-allocation priorities and laying out a three-pillar value proposition, and by repeating the line he used in August as incoming chief executive.

"But I have been equally clear consistency must not be confused with complacency. Our focus is on raising the bar on our execution."
— Andrew O'Brien, President and Chief Executive Officer

The new chief financial officer's first prepared remarks were short and numerical, and closed on the same message.

"In short, we delivered on every front. Proof that we are raising the bar on execution."
— Konnie Haynes-Welsh, Chief Financial Officer

Assessment: The transition risk we added as a bear point in August was about the framework losing its underwriter. On the first evidence the framework is intact and the new team is presenting it more explicitly than the old one did. "Delivered on every front" is a stretch for a quarter in which capital ran above the prior quarter and production came in below the guidance midpoint, but none of the misses were large. The real test remains the first full budget in February.

2. Permian Gas Back Above Zero, and Still Not Discussed

For the third consecutive call there was no sentence from management and no question from an analyst about Lower 48 gas realizations. This time the number was good news. A recovery from negative $1.44 to $2.05/MCF was the easiest win available to claim, and nobody claimed it.

"Decreases to earnings include lower gas prices of $611 million driven by lower gas realizations and lower volumes of $315 million."
— ConocoPhillips third-quarter 2026 Form 10-Q, Lower 48 nine-month results

The nine-month figure is a company quantification of the drag we estimated at about $588M pre-tax for the second quarter alone. It is backward-looking and appears only in the filing.

Assessment: Silence after a bad number can be a choice about emphasis. Silence after a good one suggests the company does not want to own a forecast for a regional price it does not control. That is a defensible position, and it leaves investors to model a product worth several hundred million dollars a quarter from pipeline schedules. We now treat the third quarter as evidence that the trough has passed, and keep the risk open because nobody inside the company has said so.

3. The Corporate Line Returns to the Beat

The quality-of-beat callout above sets out the mechanics: a $192M improvement in the adjusted corporate loss, of which $149M came from the segment's adjusted tax line. No part of the prepared remarks or the question session addressed it. The company reported a consolidated adjusted tax rate of 34.8% that looks unremarkable because a rising EMENA rate offset the corporate benefit.

"Our net debt to CFO ratio improved to 0.5x underscoring the strength of our a rated balance sheet."
— Konnie Haynes-Welsh, Chief Financial Officer

The balance sheet framing was the closest the prepared remarks came to the corporate segment.

Assessment: This is not a reason to discount the quarter heavily, because at a normalized corporate tax rate adjusted EPS would still be about $3.20 and still above consensus. It is a reason to discount the size of the beat by about a third, and to note that two of the first three quarters under this year's guidance have carried the same kind of help.

4. Capital Return: A 47.5% Quarter and an 11% Dividend Increase

The dividend rose 11% to $0.93 a quarter, larger than last year's 8% increase, and the company tied it explicitly to its top-quartile S&P 500 growth objective. The buyback rose for a second consecutive quarter, to $2.4B, and management guided it higher again.

"You should expect buybacks to trend higher in the fourth quarter as we deliver on this annual objective."
— Andrew O'Brien, President and Chief Executive Officer

The chief financial officer added the clearest statement yet of how the two halves of the distribution divide the work.

"So buybacks are also how we, you know, flex with price to deliver on that annual commitment that is so important to us."
— Konnie Haynes-Welsh, Chief Financial Officer

Assessment: The 45% commitment is on track, but the catch-up is running slightly behind the pace we said it needed. The third quarter's 47.5% sits just below the 49% to 50% second-half rate we estimated in August, and the fourth quarter now needs about 50.7%. The dividend increase deserves more thought than it got on the call. At $3.72 annualized it is about $4.4B a year at today's share count, roughly 17% of annualized nine-month CFO. That is affordable at this year's prices and at a low-$30s breakeven in 2029. Raising the fixed half of the distribution by 11% in a quarter of $97 Brent is still a choice to lock in part of a conflict-driven cash flow, and the variable half was spent fastest in September, at the quarter's highest prices.

5. The Preliminary 2027 Framework

The company gave directional 2027 guidance three months early, and the four items map exactly onto the bear points investors raise about this name.

"We anticipate capital spending to be modestly lower year on year. Consistent with the multiyear decline we outlined. Importantly, that lower capital delivers growth. We expect to see another year of low-single-digit underlying production growth driven by the Lower 48."
— Konnie Haynes-Welsh, Chief Financial Officer

Unit costs are guided lower again and the distribution target stays at 45% of CFO. On unit costs the chief executive was explicit that the reduction holds despite inflation.

"We fully expect another year of lower unit operating costs next year. And that is even with the some of the inflation that we are seeing from higher commodity prices."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: Lower capital with growth and lower unit costs is the combination that would retire our capital-discipline concern, so the direction is right. The base matters. Third-quarter capital of $3,133M and a fourth quarter guided "modestly higher" put 2026 at roughly $12.3B to $12.4B, not the $12.0B floor we expected in August. "Modestly lower" than $12.4B is a weaker commitment than "modestly lower" than $12.0B. We will judge the February budget against the 2026 number it actually lands on.

6. Beyond 2029: The Second Pillar

The structural novelty of the call was a second pillar in the value proposition: free cash flow growth after the 2029 inflection, at a structurally lower reinvestment rate.

"That would approximately double 2025 free cash flow at a $70 a barrel WTI price. And between now and then, we retain significant upside to higher prices and wider LNG spreads."
— Andrew O'Brien, President and Chief Executive Officer

"But 2029 is not the final destination."
— Andrew O'Brien, President and Chief Executive Officer

The chief financial officer restated the breakeven path management first quantified in August.

"Right now, our pre dividend free cash flow breakeven is in the mid forties, WTI. And over this period of time as we approach 2029 and beyond, that will improve to the low-$30s."
— Konnie Haynes-Welsh, Chief Financial Officer

The examples offered were Willow satellites tied back into the new hub, Surmont and Montney in Canada under the new fiscal terms, and the Middle East and Libya. The reinvestment rate at a $70 deck was put at close to 60% today, falling to "well below 50%" in the 2030s.

Assessment: This is a genuine addition to the bull case: it answers the most common objection to the inflection, which is that it is a one-off step. It also changes the shape of the commitment. A team that has defined success as growth through the next decade has given itself a reason to fund that growth. The safeguard is the reinvestment-rate number, which is specific, falsifiable and measured at a stated $70 deck, and which we will track.

7. Willow: Fabrication Past 75%, Sealift Next Summer

Process module fabrication on the Gulf Coast passed 75% complete, with completion targeted in the second quarter of 2027 and sealift to Alaska in the summer. The North Slope infrastructure civil scope was finished last winter, pipeline construction continues this winter, and drilling starts in 2027.

"And we have just exceeded the 75% completion mark, and that is an important 1 for us. As we are, you know, looking down a pathway here to wrap up that fabrication in the second quarter."
— Kirk Johnson, EVP Global Operations and Technical Functions

"everything is on track for an early 29 first production."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: The schedule is holding through the hardest construction phase. The question also asked about cost, and the answer did not give a number. Management said only that it was confident in the capital and schedule it had described before. The sealift in summer 2027 remains the next binary event, as we wrote at initiation.

8. Qatar: A Partial Restart, With New Trains in the First Half of 2027

Equity-affiliate production rose 21.8% sequentially to 179 MBOED, still 20.4% below a year ago, and equity-affiliate gas rose to 1,009 MMCFD from 865.

"You saw from our earnings materials that Qatar production has actually increased here in third quarter over second quarter. But again, it does, in fact, as you are pointing to, it remains below preconflict levels."
— Kirk Johnson, EVP Global Operations and Technical Functions

Fourth-quarter guidance spans outcomes from a continuation of the third quarter to full utilization of trains that have been running constrained. North Field East is expected in the first half of 2027, in line with the operator's published timing, with North Field South after it.

"And so as published and, you know, stated by QE, we are expecting NFE to come online. In the first half of 27"
— Kirk Johnson, EVP Global Operations and Technical Functions

Assessment: The restart is real and partial. The North Field East timing is consistent with the delay of months rather than a full year that management guided in August, which is the commitment we asked to grade. What the call did not cover is the cost of the peace scenario that is now being negotiated. A reopened Strait of Hormuz restores Qatar volumes, and it also removes the crude and LNG premium that has carried every other line of this income statement for three quarters.

9. LNG: 13 MTPA, and a Margin Running Far Above the Plan

Commercial LNG offtake rose to 13.2 MTPA from 12.2 with one more agreement. The 10-Q discloses that the company increased future purchase obligations for long-term LNG offtake, vessels and other capacity by about $9B this year. The first volumes are Port Arthur Phase 1, in which the company is also a 30% equity owner, from 2027.

"But we are trading significantly above the $10 assumption that we had And you know, Henry Hub is trading below the $4 that we had, and the costs in between effectively are locked in for us."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: The inflection is struck at a $10 TTF, and the spot market is about three times that. The arithmetic of a fixed-cost liquefaction spread is as favorable as management says while Europe pays conflict prices. That margin is also the most conflict-exposed number in the plan, and the volumes arrive just as a peace agreement would start to compress it. A $9B increase in contractual commitments is the cost of the option, and it is fixed whatever TTF does.

10. Portfolio: Norway, Kirkuk and an Appetite for the Middle East

The Norway disclosure was made earlier than the company would have liked because of Norwegian disclosure rules. Management was explicit that no decision has been made.

"So you know, as I previously communicated, we received an unsolicited offer for Norway,"
— Andrew O'Brien, President and Chief Executive Officer

On new entries the chief executive framed the Middle East as a deliberate diversification away from an OECD-heavy portfolio, inside the cost-of-supply framework. The Kirkuk terms appeared only in the 10-Q: a $0.4B purchase price before closing adjustments, including $0.2B of deferred payments due within three years of close, plus reimbursement of project costs from the July 1 effective date. On Venezuela the position was unchanged.

"But for us, to invest capital we need to see a real pathway to meaningful recovery on the $12 billion we are owed."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: Selling a mature Norwegian business from a segment taxed at 78% and adding cost-recovery barrels in Iraq is a reasonable trade on paper. The Kirkuk structure, with half the price deferred, appears to need less cash at close than the $300M to $500M range management gave in August. The pattern is the thing to watch. A new chief executive has now said publicly that the portfolio has room for "a bit more Middle East", in the same quarter that the region's conflict set the price of everything the company sells.

11. Costs, Inflation and the Depletion Explanation

Management claimed that structural cost reductions fully offset inflation, and the unit numbers support the claim this quarter.

"Across the company, structural cost reductions continue to drive improvements in our adjusted operating costs. And we see the benefit of those reductions as they are fully offsetting the impact from inflation in a higher commodity price environment."
— Konnie Haynes-Welsh, Chief Financial Officer

The inflation detail was more cautious than the headline. Fuel, logistics and chemicals are rising by double digits in places, but they are a small share of the cost base. Super-spec rigs and frac fleets in the Lower 48 are running at 90% to 95% utilization, driven largely by smaller operators adding activity.

"Utilizations have been really quite high. You know, 90-95%, respectively. Across those 2."
— Kirk Johnson, EVP Global Operations and Technical Functions

Assessment: The cost commitment we graded as missed in August was met this quarter on the metric that matters: unit operating cost fell 3.0% sequentially to $11.52 per barrel of oil equivalent. The $1B run-rate target and the $10.2B guide were still not updated in numbers. On depletion the filing's explanation changes our read. A higher book value from the Marathon purchase-price allocation and a lower proved developed reserve base at year-end 2025 are one-time resets that should lap, while the lateral-length story we proposed would have compounded. The year-end 2026 reserve report is the test.

Guidance & Outlook

The release limited itself to the fourth-quarter range and a statement that full-year capital and adjusted operating cost guidance were unchanged. The 10-Q added that DD&A guidance was unchanged. The chief financial officer gave the production context that matters.

"That would put our full year production right around 2.3 million barrels of oil equivalent per day."
— Konnie Haynes-Welsh, Chief Financial Officer

Implied ramp. Weighted by days, the first three quarters averaged 2,286 MBOED. At the 2,340 MBOED midpoint of the fourth-quarter range the full year is about 2,300 MBOED. At the bottom of the range, 2,320, it is about 2,295, the floor of the full-year guide. At the top it is about 2,305. In August we said the low end was the plannable figure, and it is now the expected one. The fourth-quarter midpoint is 1.7% above the third quarter, with turnarounds flat and Qatar carrying the uncertainty.

Capital cadence. Nine-month capital is $9,105M. Reaching the $12.0B floor would need a fourth quarter of $2,895M, which contradicts a guide for modestly higher spend than the third quarter's $3,133M. A 3% to 5% sequential increase puts the fourth quarter near $3.2B to $3.3B and the year near $12.3B to $12.4B. That is inside the range and about $300M above where we expected it to land.

Street position. Third-quarter adjusted EPS consensus sat between $2.97 and $3.06 against a $3.27 print. The early 2027 framework gives the Street a direction rather than numbers, and the ranges will not be pinned until the February budget.

Guidance style. Conservative and narrow. The company reaffirmed what it is tracking against, gave no updated cost figure despite a quarter of falling unit costs, and avoided numbers for 2027. The early directional outlook is new and constructive. The absence of CFO or free cash flow guidance, in a business that distributes a percentage of CFO, is unchanged.

Analyst Q&A Highlights

What Capital the Post-2029 Growth Requires

The question asked the new chief executive to separate sustaining from growth capital in the 2030s plan, which is the only way to judge whether a lower reinvestment rate and continued growth can coexist. The answer declined to allocate dollars by asset and instead committed to a reinvestment-rate number at a stated deck.

Q: "But I guess my question is the sustaining capital and the growth capital are 2 elements of that. How do you see the spending level as it relates to supporting that growth you have suggested today?"
— Doug Leggate, Wolfe Research

A: "But depth of the inventory we have will be investing at a reinvestment rate in the future that is basically, you know, well below 50%."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: The answer was a ratio, not a capital number, and it is the right ratio to be held to. Close to 60% at a $70 deck today falling to well below 50% in the 2030s is a measurable path. The weakness is that a reinvestment rate is a fraction whose denominator is CFO, so higher prices flatter it automatically. It only binds if it is reported at the stated deck.

How Much More of the Portfolio Goes to the Middle East

The question asked whether new organic opportunities are concentrated in the Middle East and North Africa, and how the company assesses entry risk given an OECD-weighted portfolio. Management first said the post-2029 growth does not depend on new entries, then framed the region as a deliberate diversification.

Q: "And then on the growth side, are most of the organic opportunities you are assessing kind of focused in the MENA region like what you have done with Iraq, Qatar, Libya, fiscal in Syria? And how do you assess overall risk profile when entering a new country given that ConocoPhillips' portfolio is more OECD weighted than peers who have a global footprint?"
— Phillip Jungwirth, BMO Capital Markets

A: "But what that does when we are managing a portfolio, it does give us the opportunity to basically look at putting a bit more Middle East into the portfolio. As we are so weighted OECD."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: This is the clearest statement of strategic intent on the call, and it was not hedged. The cost-of-supply and fiscal conditions that came with it are the same discipline that produced the Kirkuk terms, which look sensible. The risk-assessment half of the question got a framework rather than a method, so investors still do not know how the company prices political and repatriation risk into a cost-of-supply number.

Whether Norway Signals a More Aggressive Portfolio Strategy

The question asked whether the new regime will manage the portfolio more aggressively, using the Norway process as the example. Management rejected the word, explained the disclosure timing as a function of Norwegian rules, and made retention an explicit outcome.

Q: "I was wondering if you could maybe elaborate on your approach to portfolio management should we expect a more muscular approach to the portfolio under your regime?"
— Arun Jayaram, JPMorgan

A: "And, you know, just to be clear, if we do not receive an offer that exceeds our expectations, we are happy to keep the asset."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: The answer preserved negotiating leverage, which is the right priority while a sale process is live. It gave no valuation framework. The Norway business is roughly 5% of production in the company's highest-taxed segment, so the free cash flow it contributes is a smaller share than its volumes suggest, and that is the number a buyer's price should be compared to.

What a Ceasefire Means for Qatar

The question asked what has to happen, in a ceasefire scenario, for North Field East to ramp and for the existing Qatar footprint to run unencumbered. The answer gave a range of fourth-quarter outcomes and the first-half 2027 start, but not the conditions.

Q: "And so you know, in a base case, in a ceasefire scenario, what do you think has to happen for NFE to, you know, ramp towards full rates"
— Sam Margolin, Wells Fargo

A: "Anything from a continuation of what we are seeing in third quarter to potentially a ramp up to a full utilization of the trains that we have there on Train 3 that have been operating at a constrained level."
— Kirk Johnson, EVP Global Operations and Technical Functions

Assessment: The question was about conditions and the answer was about outcomes. That is understandable for a non-operated position in an active conflict zone, and it means the fourth-quarter guide carries a wide Qatar band. It was also the only point on the call where the peace scenario was raised, and it was raised for its effect on volumes rather than on prices.

Where LNG Margins Sit Against the Plan

The question asked how much of the 13 MTPA arrives in 2027 and where margins are. Management named Port Arthur Phase 1 as the first volume, declined to give a margin figure and then pointed to the gap between spot and the planning deck.

Q: "Can you remind us how much of that you will see in 2027 and how that ramps, and any broad thoughts on where margins are currently and into next year?"
— Kevin McCurdy, Pickering Energy Partners

A: "we have been very clear that we base that off of a $10 TTF and a $4 Henry Hub, and I think last time I looked, TTF was closer to $30."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: A planning deck one-third of spot is a conservative inflection target, which supports the bull case. It also signals that management sees the 2027 LNG contribution as a large upside to the plan, in a market whose price depends on the conflict continuing. Investors should model the plan deck and treat the gap as option value, which is how the company itself frames it.

How 2027 Absorbs Inflation

The question asked how the company offsets inflation in 2027 and how major-project capital moves into 2028. The chief executive restated the 2027 framework and attributed the room to Lower 48 efficiency, Surmont, North Field East and Port Arthur. The operations head then described inflation that is high in some categories and low in aggregate.

Q: "Can you give us a sense of you know, how are you able to offset? What do you think about inflation right now in the next year?"
— Scott Hanold, RBC Capital Markets

A: "We are saying, lower capital, low-single-digit underlying production growth, lower unit costs, and about a 45% CFO return to shareholders"
— Andrew O'Brien, President and Chief Executive Officer

Assessment: The framework answer is consistent and repeatable, and the inflation answer was honest about tight oilfield services. The 2028 half of the question did not get an answer. With rigs and frac fleets near full utilization, the efficiency gains have to keep outrunning service pricing for the 2027 framework to hold, and that is a margin of safety measured in single digits.

Whether Distributions Stay Well Above the 30% Floor

The question asked whether "sustainably higher distributions" means staying well above the company's stated 30%-of-CFO through-cycle floor, and how the dividend-buyback mix evolves. The answer pointed to the ten-year average and to a falling reinvestment rate, without converting either into a new floor.

Q: "And I guess specifically, when you think about your point and commitment to sustainably higher distributions, does that include keeping returns well above the 30% CFO baseline?"
— Devin McDermott, Morgan Stanley

A: "And as I said in my prepared remarks, we have averaged now a 45% distribution over the last decade. And I see no reason why we would not be looking for the similar kind of thing going forward, particularly as our reinvestment rate comes down."
— Andrew O'Brien, President and Chief Executive Officer

Assessment: "No reason why we would not be looking for the similar kind of thing" is an intention, not a commitment. The formal floor in the 10-Q is still "greater than 30 percent" through cycles, so the 45% annual target remains a year-by-year decision. That is appropriate flexibility for a cyclical business, and investors should not treat 45% as contractual.

Willow Scope and Cost

The question asked for a mark-to-market on both scope and cost at the midpoint of the project. The scope answer was detailed and the cost answer was a reaffirmation.

Q: "So how are we tracking on both scope and on cost And maybe you can give us a mark to market on how it is going."
— Neil Mehta, Goldman Sachs

A: "And we have just exceeded the 75% completion mark, and that is an important 1 for us. As we are, you know, looking down a pathway here to wrap up that fabrication in the second quarter."
— Kirk Johnson, EVP Global Operations and Technical Functions

Assessment: The milestones are specific, checkable and on schedule. On cost, a reaffirmation of the previously described capital is the normal answer from a project that is on budget, and it would be the same answer from one that is not yet willing to say otherwise. Alaska capital of $936M in the quarter is consistent with plan, and the sealift remains the event that settles the question.

What They're NOT Saying

1. Anything about Lower 48 gas realizations, for a third consecutive call. The realization recovered from negative $1.44 to $2.05/MCF and nobody mentioned it. The 10-Q quantified a $611M nine-month drag and warned that regional price volatility remains. There is still no forward view.
2. Why the corporate segment produced a $139M adjusted tax benefit. After the $126M tax-reserve reversal was removed, the corporate segment still carried a 64.8% adjusted tax benefit rate on a pre-tax loss. Above a normal benefit rate it supplied about a third of the quarter's beat, and it was not explained.
3. Where 2026 capital lands. A fourth quarter "modestly higher" than $3,133M puts the year near $12.3B to $12.4B. The company reaffirmed a range and did not give the number, which is also the base for "modestly lower" in 2027.
4. Whether the Kirkuk payment sits inside the capital guide. The terms, $0.4B with $0.2B deferred plus cost reimbursement from July 1, appear only in the 10-Q. The capital-guide treatment was not stated in August and was not stated now.
5. The $9B increase in LNG and vessel commitments. The 10-Q discloses about $9B of new contractual purchase obligations this year for offtake, vessels and capacity. The call discussed the margin upside and not the fixed commitment behind it.
6. What a US-Iran agreement does to the numbers. The only mention of a ceasefire came in an analyst's question about Qatar volumes. There was no discussion of the price side, and no revised mid-cycle deck. The inflection is still struck at $70 WTI, $10 TTF and $4 Henry Hub.
7. Norway's value. No framework for what an acceptable offer looks like, and no comment on what a sale would do to the consolidated tax rate or to free cash flow, given the segment's 78.3% adjusted tax rate.
8. The working capital build. The first quarter's $1,092M build has reversed by only $281M, leaving $811M outstanding for the year. It drew no comment.
9. A number for the $1B cost programme. Unit costs fell, which supports the claim, but the run-rate target and the $10.2B guide were again not updated in numbers.

Market Reaction

• Pre-print setup: the shares closed at $136.94 on November 4, up 46.3% year to date and 56.1% over twelve months, against a 52-week closing range of $85.66 to $154.03. The trailing 30 days were +5.9%. The S&P 500 was up 12.3% year to date. The stock had closed at its high of $154.03 on October 30 and then fell 11.1% in three sessions, including 5.2% on November 4 alone, as Brent fell from $113.43 to $94.62 on US-Iran talks to reopen the Strait of Hormuz.
• Session (before-open reporter, reaction is same-day): the shares rose more than 1% in premarket trading and opened at $139.72, a 2.0% gap up. They traded a $135.34 to $140.79 range and closed at $135.46, down 1.1% or $1.48.
• Volume: 9.2M shares against a 6.1M thirty-day average, 1.5 times normal.
• Peers and tape: the S&P 500 fell 4.4%, its worst session since April 2025, as AI-related stocks collapsed after the midterm elections. The energy sector fell 3.0%. Exxon Mobil fell 2.3%, Devon 2.8%, Chevron 1.9%, Diamondback 1.8%, Occidental 1.7% and EOG 1.5%. Brent rose 3.9% to $98.29, recovering part of the previous day's drop. COP outperformed the S&P 500 by 3.3 points and the sector by 1.9 points, the best result in that group.
• Since our last note: from $134.89 on August 20 the shares are up 0.4%, against a 3.8% decline in the S&P 500, a 3.3% decline in the energy sector and a 4.8% rise in Brent. Since the April 30 initiation baseline, COP is up 7.7% against 2.0% for the S&P 500.

The move happened before the print. Three sessions of peace headlines took $17.09 off the share price, about 59% of the $28.88 October rally that preceded them. The earnings release arrived into a stock that had just been repriced for a lower crude deck, and the opening 2.0% gap was the market's verdict on the quarter itself: a beat, a dividend increase and a constructive 2027 outline. The close below the prior day's level came on a tape in which the energy sector itself fell 3.0%.

Relative strength, absolute weakness. On a day when the index fell 4.4% and crude rose 3.9%, a 1.1% decline is a strong relative result, and it was the best among its large-cap peers. Read the other way, a stock with this much crude sensitivity failed to rise on a 3.9% crude rally. The market is no longer paying for higher crude on the day. It is pricing the probability that the conflict premium disappears.

What it means for the rating. Since August the stock has done what a Hold should not quite do: it has beaten the S&P 500 by about four points while going nowhere in absolute terms. Over that period Brent futures ran to $116.72 on October 23 and back to $94.62. The fundamental gains of the past two quarters are real, but the share price still contains most of the conflict premium we identified in August, and the last week showed how quickly that premium can move.

Street Perspective

Debate: What Does a US-Iran Deal Do to This Equity?

Bull view: the investment case was never a conflict trade. The $7B inflection is struck at $70 WTI, $10 TTF and $4 Henry Hub, the free cash flow breakeven is in the mid-$40s today and falls to the low $30s by 2029, and the LNG spread is locked in on the cost side. A peace deal also restores Qatar volumes and removes the company's largest non-operated risk. Unhedged torque is an option on a longer conflict that the business does not need to exercise.

Bear view: the share price is a conflict trade, whatever the business is. The stock is up about 45% year to date and fell 5.2% on a single day of peace headlines. A year ago, at $64.93 WTI, this company earned $1.61 a quarter. At today's share count that is about $6.71 a year, which puts the shares at roughly 20 times earnings on a pre-war deck. The fourth quarter will also absorb a falling JCC lag in Asia Pacific.

Our take: both are right about different things. The bull case describes the business accurately and the bear case describes the price. The shares ended 2025 at about 15 times that year's adjusted earnings. The same multiple on pre-war earnings power at today's share count gives about $102, and crediting the cost programme, the buyback, the first LNG volumes and a $70 deck moves that toward the $115 level we named in August, not to $135. Until the price or the earnings power closes that gap, the risk and reward are balanced, which is a Hold.

Debate: Is Post-2029 Growth a Better Story or a Looser Framework?

Bull view: the new pillar answers the oldest objection to the inflection, that it is a one-off step. Two decades of Lower 48 inventory, Willow satellites using a new hub, Surmont under better fiscal terms and Middle East redevelopment at a $30 cost of supply support growth at a reinvestment rate falling from about 60% to well below 50%. Distributions are a percentage of CFO, so growth in CFO is growth in distributions.

Bear view: a new chief executive extending the horizon five years beyond the inflection is the classic setup for capital creep. In a single call the team named Willow satellites, a Surmont expansion, a broader surfactant rollout, Woodford and Barnett appraisal and "a bit more Middle East", while 2026 capital drifted toward the middle of its range and LNG commitments rose by $9B.

Our take: the reinvestment-rate commitment is specific enough to hold management to, and the 2027 framework points the right way. We would weight the bear concern more than the market currently does, because every item on the growth list is individually reasonable and they compete for the same dollars. The February budget will show whether "modestly lower" means lower than $12.0B or lower than $12.4B.

Debate: Is an 11% Dividend Increase at $97 Brent the Right Use of a Peak?

Bull view: top-quartile S&P 500 dividend growth is a commitment management has made credible, and the falling breakeven makes it affordable through the cycle. At about $4.4B a year the dividend is roughly 17% of annualized nine-month CFO, and the buyback exists precisely to flex with price. Shareholders get a growing fixed claim and a variable one.

Bear view: raising the fixed claim by 11% in a quarter of $97 Brent locks part of a conflict-driven cash flow into a payment the company will not want to cut. The variable claim behaved pro-cyclically, with September, the highest-priced month, taking 41% of the quarter's repurchased shares at $132.39. If crude normalizes, the dividend's share of CFO rises just as the buyback has to shrink.

Our take: the dividend is affordable and the increase is defensible. The more legitimate criticism is buyback timing, which the annual-percentage framework partly forces. We would rather see the fourth-quarter step-up executed at the post-peace-talk price than at October's, and the monthly 10-Q disclosure will show it.

Model Update Needed

Valuation impact: at $135.46 the equity is about $160.2B of market capitalization on 1,182.3 million shares, and about $171.9B of enterprise value after $23.3B of debt, $10.4B of cash and short-term investments and $1.1B of liquid long-term investments. Annualized nine-month adjusted EPS of $8.40 gives $11.20 and about 12.1 times. The third quarter alone annualizes to $13.08 and 10.4 times. Annualized nine-month CFO gives about 6.5 times EV to cash flow, and annualized nine-month free cash flow of about $14.2B is an 8.8% yield. The new dividend yields 2.75%. All of those multiples are struck on nine months in which dated Brent averaged $94.05. The pre-war comparison is the one that matters: the third quarter of 2025, at $64.93 WTI, produced $1.61 of adjusted EPS, or about $6.71 a year at today's share count, which puts the shares at about 20 times. The fourth quarter of 2025, at $59.14 WTI, produced $1.02. The cost programme, the buyback and the first LNG volumes will close part of that gap by 2027, but not all of it. The shares ended 2025 at $93.61, about 15.2 times that year's $7,742M of adjusted earnings, or about $6.18 a share. The multiple paid here is mostly a statement about how long the conflict lasts.

Thesis Scorecard Post-Earnings

Scored against the standing thesis carried forward from the second-quarter report, with the pillar status tags shown before and after this quarter.

Overall: the thesis strengthened modestly. All four bull pillars were confirmed, and the second was extended by a post-2029 growth case with a measurable reinvestment-rate commitment. Two bear points de-escalated: the Lower 48 gas realization went from the worst number in the income statement to a contributor, and unit depletion decelerated with a cause that should lap. The leadership transition passed its first test. Against that, the quality of the beat slipped back toward the first quarter's pattern, capital is running above where we expected it, and the macro-premium bear point was demonstrated in real time in the three sessions before the print.

Action: hold. We grade the three triggers we set in August as they were written. The first, a pullback that restores the roughly $115 entry price without impairing the 2029 schedule, has not happened: the stock is at $135.46. The second, a credible forward disclosure on Lower 48 gas realizations, has not happened either, although the realization itself has recovered. The third, a first capital budget from the new team that lands inside the framework, is directionally met by the 2027 outline, and the budget itself arrives in February. One partial trigger is not enough for an upgrade. The business is better than it was in August and the price is the same, while the conflict that supports that price is now being negotiated away. We would move constructive if a de-escalation-driven pullback brings the shares toward the $115 level with the 2029 schedule intact, or if the February budget confirms capital below $12.0B with growth. Absent either, the risk and the reward are balanced.