Exxon Mobil Doubles Profit to $14.5B and Still Sits 12% Below Its High: Permian Hits 1.8M Barrels a Day

ExxonMobil posted second-quarter 2026 earnings of $14.5 billion, or $3.48 per share, with adjusted earnings of $14.7 billion, or $3.52 per share. Revenue came in at $116.0 billion against a $97.7 billion estimate. Net income more than doubled from $7.1 billion in the same quarter of 2025, and jumped from $4.18 billion in the first quarter of 2026.

The stock fell 2.42% on the print. Adjusted EPS came in ten cents below the $3.58 consensus, and that single miss overshadowed everything else in the release. Shares slid roughly 2% in premarket trade on July 31.

XOM has since recovered. The stock closed Thursday at $154.84, up $3.21 or 2.12% from a $151.63 prior close, in a $151.84 to $154.87 range, with after-hours trade at $154.82. That puts the shares 12.2% below the $176.41 fifty-two-week high and 46.7% above the $105.52 low.

At that price the market capitalization is $636.69 billion across 4.11 billion shares, the trailing P/E is roughly 19.9 on TTM EPS of $7.76, and the dividend yield is 2.72% on a $1.03 quarterly payout with an ex-date of August 17, 2026. Beta sits at 0.16 — the lowest of any mega-cap in the index and a reminder that this is a commodity proxy, not a market proxy.

The operating detail was the strongest in years. Cash flow from operating activities reached $23.6 billion. Free cash flow hit $17.2 billion. Shareholder distributions totaled $9.4 billion — $4.3 billion of dividends and $5.1 billion of buybacks. Net debt fell by more than $7 billion. Upstream exploration and production earnings came in at $7.9 billion against $5.4 billion a year earlier.

All of that happened while roughly 10% of upstream production was offline because of Middle East disruption.

The problem is what comes next. Brent averaged $103 a barrel in the second quarter — $117.29 in April, $107.14 in May, $85.40 in June. It traded at $83.40 Friday. The official forecast has it averaging $74 in Q3 and $70 in Q4. The commodity tailwind that produced a doubled quarter is already gone, and the president spent August 3 telling this company to give money back.

The Refining Miss Was Real and It Was Defensible

The ten-cent shortfall came from a specific place. Management attributed it directly to the refining business, explaining that massive disruption in global crude and product markets made accurate pricing forecasts unusually difficult during the quarter, and that unpredictability produced the gap versus estimates.

That is a genuinely credible explanation rather than a deflection. Crude moved from $117.29 in April to $85.40 in June on the Brent average — a $32 swing inside twelve weeks — while product cracks blew out and then partially normalized. A refining system buying feedstock weeks in advance and selling product into a market repricing daily will produce forecast error. Every integrated reported the same dynamic.

The underlying refining result was a turnaround rather than a deterioration. Downstream captured outsized margins by leveraging integrated value chains, trading capability and advantaged assets during a period when the conflict tightened global supply of both crude and refined products. Specialty Products delivered record earnings, helped by a tight basestock market and the company's synthetic basestock capabilities in Singapore and Rotterdam.

Put the miss in scale. Ten cents on $3.58 is a 2.8% shortfall against a quarter where revenue beat by $18.3 billion — 18.7% above estimate — and net income doubled. The market chose to price the two-cent-per-share forecast error rather than the $9.4 billion of distributions.

That reaction is informative about positioning rather than fundamentals. Energy majors had run hard into the print. XOM had pre-announced that higher crude prices would add $3.5 billion to $3.9 billion to Q2 upstream earnings versus Q1, with gas pricing roughly neutral at a $200 million swing either way. The stock rallied over 1% on that disclosure alone in mid-July. By the time results landed, the upstream windfall was fully in the price and the only surprise available was negative.

Peer results confirm the sector-wide windfall was priced rather than discovered. Chevron reported roughly $12.1 billion, up from about $2.5 billion a year earlier and its highest quarterly earnings in at least six years. Valero posted its strongest quarterly profit since the 2022 energy crisis. Saudi Aramco reported a jump in adjusted net income on August 4.

Everyone printed. Nobody got paid for it.

Cash Generation Was the Actual Headline

Strip the earnings-per-share arithmetic and look at what the business converted to cash, because that is where the quarter was exceptional.

Operating cash flow reached $23.6 billion. Free cash flow came in at $17.2 billion. Against a $636.69 billion market capitalization, that single quarter of free cash flow represents a 2.70% yield — 10.8% annualized if repeated, which it will not be at $83 Brent, but a useful marker of the earnings power at the top of a commodity cycle.

Cash capital expenditure ran $13.0 billion year to date, which implies roughly $6.4 billion in the quarter against $23.6 billion of operating cash. That is a 27% reinvestment rate at the peak of the price cycle — disciplined for a company with a $140 billion capital program running through 2030.

The corporate plan frames the spending envelope. Capex is guided to $28 billion to $33 billion annually across 2026 through 2030, with $140 billion earmarked for major projects and the Permian development program and expected returns above 30% over the life of those investments. At the current run rate, the company is tracking near the lower end of that range.

Balance sheet management was the quarter's quiet achievement. Net debt fell by more than $7 billion. That is deleveraging into a windfall rather than spending it, and it directly contradicts the pattern that destroyed this sector's returns in prior cycles — where peak-price quarters funded peak-price acquisitions and greenfield capacity that stranded when prices reverted.

Management guidance on the forward path is aggressive. The chief financial officer projected that 2030 free cash flow will double versus 2025 levels. The plan targets $20 billion of incremental earnings growth and $30 billion of incremental cash flow growth to 2030, generating a further $165 billion in surplus cash across the plan period to fund increased distributions.

Set that against the $65 real Brent assumption underpinning the plan and the numbers become interesting. Spot Brent is $83.40 — $18.40 above the deck. Even the official Q4 forecast of $70 sits above it. Every dollar of Brent above $65 is incremental to a plan already modeling doubled free cash flow.

That is the structural case for owning this at 19.9 times earnings.

Capital Returns: $9.4 Billion and a 42-Year Dividend Streak

Shareholder distributions totaled $9.4 billion in the quarter — $4.3 billion of dividends and $5.1 billion of share repurchases. Against $17.2 billion of free cash flow, that is a 55% payout with the remainder going to debt reduction.

The dividend mechanics matter for anyone positioning now. The quarterly payout is $1.03 per share with an ex-date of August 17, 2026, which means the entitlement comes out of the price ten sessions from Thursday's close. On $154.84 that single quarterly distribution is 0.67%, annualizing to the 2.72% yield.

Note how far that yield has compressed. The 2025 dividend yield was 3.32% with a 59.70% payout ratio. The year before it was 3.57% at a 49.00% payout. At 2.72% the shares are yielding 60 basis points less than a year ago — entirely because the price has run, not because the payout has been cut. The dividend has been increased for 42 consecutive years.

Buyback pace has been consistent at a $20 billion annual run rate, with the same $20 billion planned for 2026 assuming reasonable market conditions. At $5.1 billion in Q2 the company is tracking slightly above that. On 4.11 billion shares outstanding, $20 billion of repurchases at current prices retires roughly 129 million shares — 3.1% of the float annually.

That combination — a 2.72% dividend plus roughly 3.1% of share count retired — produces a 5.8% total shareholder yield before any price appreciation. For an asset with a 0.16 beta, that is a genuinely competitive return profile against a 4.60% ten-year Treasury.

The comparison that matters is against the Fed. The target range is 3.50%–3.75% with the effective funds rate at 3.63%. A 2.72% dividend on its own loses to cash. A 5.8% total shareholder yield with commodity optionality attached does not, and that spread is why the shares trade near the top of their 52-week range despite a 19.9 times multiple.

The vulnerability is that buybacks are discretionary and free cash flow is commodity-dependent. At $70 Brent in Q4, a $20 billion annual pace becomes a stretch against $28 billion to $33 billion of capex.

Permian Hit 1.8 Million Barrels and Guyana Is at 900,000

The upstream operating result is what separates this quarter from a pure price windfall.

The Permian Basin set a production record above 1.8 million oil-equivalent barrels per day. Excluding the Middle East disruption, the upstream business delivered its highest production volumes in more than two decades. Upstream exploration and production earnings reached $7.9 billion against $5.4 billion a year earlier — a 46% increase.

Guyana produced approximately 900,000 barrels per day gross from the Stabroek block, with the fifth production vessel, Errea Wittu, on track to start up by year-end. Management disclosed that Guyana development has accelerated investment recovery by two years — the project is paying back capital faster than the original model assumed.

The Guyana pipeline is the longest-duration growth asset in large-cap energy. Eight developments are planned by 2030 following the addition of Hammerhead and Longtail. Total production capacity on an investment basis is expected to reach 1.7 million barrels per day, with gross production growing to 1.3 million barrels per day by 2030. Uaru is anticipated to start in 2026 and Whiptail in 2027. ExxonMobil Guyana Limited operates with a 45% interest, Hess Guyana Exploration holds 30%, and CNOOC Petroleum Guyana holds 25%.

Aggregate the plan and total upstream production is targeted at 5.4 million oil-equivalent barrels per day by 2030 — an increase of nearly 1 million barrels from the 2024 base and the highest production level the company will have seen since the 1970s. Advantaged assets, defined as the Permian, Guyana and LNG, are modeled to grow by 1.2 million barrels per day and represent more than 60% of total upstream volumes.

The Pioneer acquisition already pushed advantaged assets above 50% of upstream production three years ahead of schedule, which is the single most important structural fact about this portfolio. Advantaged barrels carry lower cost of supply and higher returns, which means the earnings sensitivity to a Brent decline from $103 to $70 is materially lower than the headline price move suggests.

By 2030, at $65 real Brent, $3 Henry Hub and $6.50 TTF, the plan delivers an additional $9 billion in upstream annual earnings — more than 50% above 2024. That is growth modeled on a price deck $18 below spot.

The LNG Build Is the Diversification Nobody Prices

Four world-class LNG projects are under development, with the company expecting to surpass 40 million metric tons per annum of LNG sales by 2030.

The portfolio geography is the point. Golden Pass in the United States, the Qatar North Field East expansion, Papua New Guinea's Papua project, and Mozambique's Rovuma development. Golden Pass and Qatar North Field East were targeted for first sales near the end of 2025, with final investment decisions at Papua and Rovuma sequenced through 2025 and 2026.

That footprint answered the most pointed question on the earnings call. Asked about diversifying the LNG portfolio away from the Middle East given the Hormuz disruption, management declined to extrapolate current events into a view of long-term regional instability — the world needs Middle East resources — while noting that Mozambique, Papua New Guinea and Golden Pass will diversify supply, and that the company remains open to opportunities in the region.

That is the correct answer strategically and an uncomfortable one for anyone underwriting the political risk. Exxon is not retreating from a region where a strait has been functionally closed since February 28 and where roughly 10% of its upstream production went offline this quarter.

The LNG economics are the reason. Forty million tonnes per annum of sales into a market where European gas has been repriced by the same conflict, with a TTF planning assumption of $6.50 per mmbtu against spot levels that have run far above it through 2026, is a substantial earnings stream that does not correlate to Brent.

Diversification within the downstream also delivered. Specialty Products posted record earnings on a tight basestock market, with the Proxxima program advancing — a 35 kiloton plant online and a final investment decision taken on a blending plant. Customer feedback was described as strong with penetration expected to take time.

Structural cost work sits underneath all of it. The company has achieved $16.3 billion of cumulative structural savings since 2019 and targets $20 billion by 2030 through digital transformation initiatives. That is $3.7 billion of incremental cost reduction still to come — roughly 26% of a single quarter's earnings, delivered annually and independent of price.

Up to $30 billion of lower-emissions investment opportunity rounds out the capital allocation. That is optionality, not a commitment.

Ten Percent of Upstream Went Offline and the Quarter Still Doubled

The Middle East disruption is the detail that makes this print more impressive than the headline number.

Approximately 10% of upstream production was temporarily lost to the conflict. On a base tracking toward 4.5 million-plus oil-equivalent barrels per day, that is roughly 450,000 barrels a day of volume that did not produce revenue during the most profitable pricing quarter in years. The Strait of Hormuz has been effectively closed since February 28, with production shut-ins exceeding 10 million barrels per day across six Gulf producers as storage filled and tankers could not load.

Exxon delivered $14.5 billion anyway, and it did so by leaning on the parts of the portfolio that were unaffected. Record production outside the Middle East in more than two decades. A Permian record above 1.8 million boe/d. Guyana at 900,000 bpd gross. Integrated value chains and trading capability capturing outsized margins as the conflict tightened both crude and product supply.

Management framed the quarter as shaped by disruption but defined by execution. The numbers support that framing.

The forward asymmetry is favourable and underappreciated. If Hormuz reopens, that 450,000 barrels a day of shut-in Exxon production returns — but into a market where Brent falls toward the $74 Q3 forecast and the $70 Q4 projection. Volume recovers, price declines. If the conflict persists, the volume stays offline but the price premium stays on.

Neither outcome is clearly better for earnings, which is precisely why the stock has been range-bound between $150 and $176 for months. The two variables offset.

Where it matters is for the 2027 and 2028 earnings path. The current forecast has most crude production returning to near pre-conflict averages by the end of this year and the majority of shut-in production back online in the first quarter of 2027, with Brent averaging $65 in 2027. On that deck, Exxon gets its 450,000 barrels back at a price that matches the company's own $65 real planning assumption exactly.

That is the base case the plan was built for, and the plan projects doubled free cash flow by 2030 on it.

The Brent Problem: $103 Became $83 and the Forecast Says $70

Here is why the stock has not run to new highs on a doubled quarter.

Brent averaged $103 a barrel in the second quarter of 2026. US oil futures averaged roughly $92 a barrel from April through June, about 27% higher than the first quarter. Brent traded at $83.40 Friday, up 1.1%, with WTI for September delivery at $77.91, up 0.8%.

The official forecast path is explicit: Brent to average $74 in the third quarter — a $27 downward revision from the prior month's projection — falling to $70 in the fourth quarter and averaging $65 in 2027. Spot sits $9.40 above the Q3 number with two months of the quarter remaining.

Run the earnings sensitivity. The company pre-announced that higher crude prices would add $3.5 billion to $3.9 billion to Q2 upstream earnings versus Q1. Reversing a comparable price move in the other direction — Q2's $103 average to a Q3 average near $80 — implies a similar order of magnitude reduction. Q2 upstream earnings of $7.9 billion could compress toward $5 billion at those levels, which is roughly where they sat a year ago at $5.4 billion.

Refining is the offset and it may be substantial. European distillate refining margins have been driven toward 20-year highs by extreme heat and drought disrupting refinery efficiency and power generation. A refining system with available capacity captures that crack regardless of the flat crude price, and Exxon's downstream demonstrated exactly that capability in Q2.

The structural buffer is the cost base and the asset mix. Advantaged assets — Permian, Guyana, LNG — represent over half of upstream production and are being grown to more than 60%. Those barrels carry lower cost of supply, which compresses the earnings sensitivity to a price decline. Layer $16.3 billion of achieved structural savings on top, heading to $20 billion, and the downside from $83 Brent to $70 is meaningfully less than a naive price-times-volume calculation implies.

Which is the entire investment case in one sentence: the plan assumes $65 Brent, spot is $83.40, and the forecast bottoms at $65 in 2027. Exxon is not a bet on high oil prices. It is a bet that the machine compounds at the price the company already models.

The Political Risk Is Live, Specific and Unhedgeable

On August 3 the president publicly accused ExxonMobil and Chevron of making "too much money" off higher fuel prices and said the companies should "give some of that back to the public," demanding they cut retail prices. He described it as a break from his usual alliance with the industry and said he would say it "loud and clear."

That was not the first intervention. On June 24 the administration accused Exxon, Chevron, Shell and BP of price gouging and ordered a Department of Justice investigation, arguing crude prices had fallen roughly 36% without pump prices following suit. That probe remains active, and the criticism has since broadened from pump-price behavior to overall profit levels.

The arithmetic behind the political pressure is straightforward and getting worse. The national average gasoline price stood at $4.09 to $4.10 a gallon in early August against $2.98 on February 27 — before the war — and roughly $3.15 a year earlier. That is nearly 40% higher at the pump. Diesel topped $5 a gallon, the highest since December 2022. US crude prices are up approximately 20% from the February 28 start of hostilities.

Policy responses to date have been indirect. A 60-day Jones Act waiver was issued to reduce domestic transport costs, though independent analysis estimates the measure would cut gasoline prices by roughly three cents per gallon. Venezuela sanctions were eased to allow US companies to transact with the state oil company. Strategic Petroleum Reserve releases have been deployed.

None of that touches Exxon's earnings directly. What would is a windfall profit tax, a mandated price cap, or an adverse outcome from the gouging investigation — and all three become more plausible with gasoline at $4.09 heading into a midterm cycle.

The relative comparison sharpens the exposure. Chevron earned roughly $12.1 billion against about $2.5 billion a year earlier. Exxon earned $14.5 billion against $7.1 billion. Canadian producers signaled at an April conference that windfall gains would flow to shareholders rather than fund new investment. Exxon returned $9.4 billion in the quarter and reduced net debt by $7 billion, which is exactly the behavior that draws the "give it back" framing.

This is a risk that cannot be hedged with options or offset by operating performance. It is a policy tail, and it is why the shares trade 12.2% below their high.

Valuation: 19.9x Earnings With a $43 Target Spread

The multiple has expanded and the market is genuinely split on whether it should have.

At $154.84 with TTM EPS of $7.76, XOM trades at roughly 19.9 times trailing earnings — up from 19.51 at Thursday's $151.63 open. Market capitalization is $636.69 billion. Price-to-book sits near 2.26. EBITDA runs $70.72 billion at an 18.50% margin. Beta is 0.16.

Twenty-five analysts carry an average rating of Buy with a twelve-month price target of $167.73, implying 8.32% upside from $154.84. The dispersion is the interesting part: a $185 high estimate and a $142 low. That $43 spread is 27.8% of the share price.

Individual actions in the past week captured both sides. One firm upgraded to Hold from Sell, lifting its target to $142 from $130 and citing exceptionally strong Q2 results. Another downgraded to Hold from Buy. Targets in circulation range from $155 to $182. Ten recommendations are buys against one sell.

Context on the trailing multiple: 2025 revenue was $323.91 billion, down 4.52% from $339.25 billion, with earnings of $28.84 billion, down 14.36%. Q2 2026 alone delivered $14.53 billion — half of the entire 2025 earnings base in three months. TTM EPS of $7.76 therefore embeds one extraordinary quarter, which means the 19.9 times multiple flatters the underlying earnings power in the wrong direction: forward earnings will be lower, so forward P/E is higher.

That is the bear case on valuation. A cyclical trading near the top of its 52-week range at 19.9 times peak-adjacent earnings, on a commodity forecast to decline 20% by year-end, with an active federal investigation and a president demanding price cuts.

The bull case is the plan. Twenty billion dollars of earnings growth and $30 billion of cash flow growth to 2030. A $165 billion surplus cash projection over the plan period. Production reaching 5.4 million boe/d — the highest since the 1970s. Free cash flow doubling versus 2025. All modeled at $65 real Brent, $18.40 below spot.

Both readings are defensible at $154.84, which is why the target range spans $142 to $185.

Technical Structure: $150 Broke, $160 Is the Target

The chart turned in July and the levels are clean.

XOM broke through the resistance zone around $150 — a confluence of the $150 round number, the resistance trendline of the daily down channel dating from March, and the 50% Fibonacci retracement of the downward impulse that began in May. That break projected a move toward $160, and Thursday's $154.87 high is roughly halfway there.

The stock trades near the top of its 52-week range and above its 200-day simple moving average, with the weekly chart testing the 50-week exponential moving average. The daily technical composite reads as a strong buy on moving averages and momentum indicators.

The countervailing structure is the series of lower highs stretching back to late March. Price has returned to that falling trendline as crude rose, and the question is whether it breaks. A confirmed close above $160 would invalidate the pattern and open the $176.41 fifty-two-week high — 13.9% above Thursday's close.

Support levels: $151.63 at Wednesday's close is immediate, then $151.15 at the recent session low. Below that, $150 is the structural pivot — losing it puts the stock back inside the March-to-July down channel and targets $145, then the $142 low-end analyst estimate. The 52-week low at $105.52 is the tail.

Volume has been healthy at 12.23 million against a 15.11 million average, which means the recovery from the earnings drop has come on normal rather than exceptional participation. That is neither confirmation nor a red flag.

The near-term calendar matters for positioning. The $1.03 dividend goes ex on August 17, which typically attracts yield buyers into the date and produces mechanical price adjustment on it. The next earnings release is October 23, meaning eleven weeks of pure commodity and policy beta with no company-specific catalyst.

In between sit the August 11 energy outlook update, US July CPI on August 12, and whatever emerges from the Hormuz negotiations — Iran's draft terms for the strait proved stricter than markets had priced, with a proposed ban on US and Israeli vessels and penalties equal to 20% of cargo value.

Trade the $150 to $165 band. Above $160 the technical case improves materially; below $150 it breaks.

What the Macro Repricing Did for the Sector

Friday's payrolls collapse changed the discount rate for every long-duration cash flow, and integrated energy is a long-duration cash flow with a commodity option attached.

July payrolls printed minus 23,000 against an 80,000 consensus, with May and June revised down a combined 103,000 and participation sliding to 61.4%. Federal Reserve September hike odds fell from 67% a week ago to 44%. The 10-year Treasury yield dropped to roughly 4.60% from 4.67%. The dollar weakened.

For XOM specifically, three transmission channels matter. Lower nominal yields raise the present value of a $165 billion surplus-cash projection running to 2030. A weaker dollar mechanically supports dollar-denominated crude, which supports upstream earnings. And a Fed that stays parked rather than tightening into a slowdown improves the 2027 demand path that the $65 Brent forecast assumes.

Against that, a contracting labour market with falling participation consumes less gasoline, less diesel and less jet fuel. Retail trade employment fell 19,000 in July. That is demand destruction at the pump, and it arrives on top of a $4.09 national average that is already suppressing miles driven.

The equity backdrop was supportive. The S&P 500 traded within four points of its record close, the Nasdaq Composite gained 0.86%, and gold futures ripped 3.02%. In a session where risk assets rallied on a Fed pause, a 0.16-beta energy major with a 5.8% total shareholder yield is not the first thing bought — but it is not sold either.

The sector-wide read from Q2 reporting season was that every producer and refiner printed windfall numbers. Chevron delivered its best quarter in at least six years. Valero posted its strongest profit since 2022. A major shale producer beat on higher crude prices. Another posted its highest quarterly profit since 2022 on price and output.

Universal beats across a sector produce no relative alpha and considerable political attention. That combination is exactly what XOM is trading now: excellent absolute results, no differentiated re-rating, and a policy overhang that scales with the results.

Scenarios Into Q3 Earnings on October 23

Base case, roughly 45% weight: Brent holds $75 to $85 into the fourth quarter, above the $74 Q3 and $70 Q4 forecasts but well below Q2's $103 average. Q3 earnings compress toward $9 billion to $11 billion as upstream gives back the price windfall while Permian and Guyana volumes grow and refining cracks stay elevated. The $20 billion buyback pace holds, the dividend rises for a 43rd consecutive year, and the stock ranges $148 to $165. Base target $160.

Bull case, roughly 30%: Hormuz negotiations collapse, Brent holds above $85, and the 450,000 barrels a day of shut-in Exxon production stays offline while pricing more than compensates. Errea Wittu starts up on schedule, lifting Guyana above 900,000 bpd gross, and Permian holds above 1.8 million boe/d. Free cash flow runs near $15 billion quarterly, buybacks accelerate, and the stock clears $160 and targets the $176.41 high and then the $185 top-end estimate. Upside 19.5%.

Bear case, roughly 25%: a Hormuz reopening is confirmed, Brent falls to $74 and then $70, and Q3 upstream earnings drop toward $5 billion. Simultaneously the gouging investigation produces an adverse finding, or a windfall levy enters the legislative conversation with gasoline near $4.09 and midterms approaching. The stock loses $150, breaks back into the March-to-July down channel, and targets $145 and then the $142 low-end estimate. Downside 8.3%.

The distribution skews modestly favourable from $154.84 — roughly 3.3% to the $160 technical target versus 3.1% to the $150 structural support — but the tails are asymmetric in the wrong direction. The bull case pays 19.5%. The bear case with a policy accident pays considerably worse than the $142 modeled floor, because a windfall tax would reprice the entire distribution framework that supports the 5.8% shareholder yield.

The one thing that will not change across scenarios is the operating machine. A Permian record above 1.8 million boe/d, eight Guyana developments by 2030 growing to 1.3 million bpd gross, 40 mtpa of LNG sales, and $20 billion of structural savings are all price-independent.

Levels and Verdict

ExxonMobil at $154.84 just reported $14.5 billion of net income on $116.0 billion of revenue, $23.6 billion of operating cash flow and $17.2 billion of free cash flow. It returned $9.4 billion to shareholders, cut net debt by more than $7 billion, set a Permian production record above 1.8 million oil-equivalent barrels per day, held Guyana at approximately 900,000 barrels per day gross, and delivered its highest non-Middle East upstream volumes in more than two decades — all while roughly 10% of upstream production was offline.

The stock fell 2.42% because adjusted EPS came in ten cents light on refining forecast error during a quarter when Brent moved $32 in twelve weeks.

The map: $150 is the structural pivot, cleared in July along with the March down-channel trendline and the 50% Fibonacci retracement. Above spot, $160 is the immediate target, then $176.41 at the 52-week high and $185 at the top of the analyst range. Support at $151.63, then $151.15, then $150 — losing it returns the stock to the down channel and targets $145 and $142. The $1.03 dividend goes ex on August 17.

The bull case is arithmetic. The plan assumes $65 real Brent. Spot is $83.40. The 2027 forecast bottoms at $65. Production reaches 5.4 million boe/d by 2030 — the highest since the 1970s — with advantaged assets above 60% of the mix, $20 billion of structural savings, $165 billion of projected surplus cash, and free cash flow doubling versus 2025. At 19.9 times trailing earnings and a 5.8% total shareholder yield with a 0.16 beta, that is a defensible holding.

The bear case is not the commodity. It is Washington. Gasoline at $4.09 against $2.98 pre-war, diesel above $5, an active federal price-gouging investigation opened June 24, and a president who on August 3 told this company publicly to give the money back.

Verdict: own it above $150 with a stop below $148, first target $160, extension $176.41. Take the August 17 dividend. Size the position for a policy event you cannot hedge, and understand that the $167.73 consensus target embeds no windfall levy. The machine is working. The politics are not.

That's TradingNEWS