Diamondback Energy, Inc. (FANG) Q3 2026 earnings review
Diamondback gas prices turn positive, but subsidiary deals lift debt
Diamondback Energy, the West Texas oil and gas producer, generated $2.1 billion of free cash flow as local natural gas prices turned positive again. Total revenue rose 38% from a year ago, though it slipped 2% from the second quarter as oil prices cooled to $87 a barrel. Chief executive Kaes Van't Hof raised full-year production and capital spending plans while lifting the quarterly dividend by 7%.
| Total revenue | $5,431M +38.4% from a year ago |
|---|---|
| Profit per share, excluding one-offs | $5.86 +90.3% from a year ago |
| Daily combined production | 1,034 MBOE/d above 995–1,015 MBOE/d plan |
| Full-year production and spending outlook | Raised oil +2 MBO/d; capital budget +$75M |
⚖️ Verdict: 🟢 Bullish
The story got better because the company fixed its natural gas pricing drag and accelerated its expansion into the deeper Barnett shale. Unhedged gas prices rebounded from negative territory to $1.12 per thousand cubic feet, and the producer bought a stake in a Gulf Coast gas pipeline plus $809 million of mineral rights through its Viper subsidiary. One caution: Viper's borrowing pushed consolidated net debt up by $513 million, and completing wells faster than drilling them continues to draw down uncompleted well inventory.
The question now is whether deeper Barnett shale wells and gas pipeline deals can drive per-share cash flow growth without higher capital spending. Optimists see years of low-cost inventory in the new acreage, while skeptics note that oil output is plateauing and full-year capital budgets just crept higher. Fourth-quarter well results from the first full Barnett pad will show the unit economics.
🐂 Bull Case
Natural Gas Prices Turn Positive Again
Diamondback produces large volumes of natural gas alongside its West Texas oil, and local pipeline bottlenecks pushed its unhedged gas price to negative $2.15 per thousand cubic feet last quarter. In the third quarter, the unhedged price rebounded to a positive $1.12, turning a quarterly revenue drag back into roughly $151 million of sales by our math.
The Texas producer also bought a 7.5% ownership stake in the Solitude Pipeline System, "a Permian-to-Katy natural gas pipeline". Total production reached 1,034 thousand barrels of oil equivalent per day (MBOE/d), which combines oil, gas and liquids into one volume measure. Because gas pipes are opening up, the company lowered its full-year gathering and transportation cost outlook by $0.10 per barrel equivalent.
What to watch: the exact share of gas sales still tied to local Waha hub prices in the quarterly filing. A drop toward the 40% year-end target would protect cash flow if winter maintenance fills local pipes again.
Barnett Drilling and Mineral Purchases Speed Up
Diamondback is expanding into deeper rock layers like the Barnett shale to extend its drilling inventory while stretching well lengths to lower costs. Its royalty subsidiary Viper Energy bought the McElroy Ranch for $529 million in September, adding 7,359 net royalty acres in "an expected core geologic fairway of Barnett development in the western Midland Basin".
- Barnett gross wells drilled: 14 in Q3, double the 7 drilled in Q2
- Average completed well length: 13,584 feet, up 13.4% from last quarter
- Nearby Barnett well recovery: about 80 barrels of oil per foot after 12 months
- Full-year completed footage plan: raised by 100,000 feet to 6.2–6.6 million feet
The McElroy Ranch is 96% undeveloped and adds 40.9 net drilling locations operated mostly by Chevron and Diamondback. What to watch: completed well costs and initial output from the four-well Spanish Trail Barnett pad in Q4, which will show if full-scale development matches pilot returns.
Standalone Debt Falls While Payouts Rise
Management dropped its fixed payout formula earlier this year to pay down parent-company debt and buy back shares when prices dip. Standalone net debt at the parent level fell by $269 million in the quarter to $10.42 billion, and in October the oil producer paid off all $698 million of its 2026 notes and retired $195 million of long-dated bonds at 91% of face value.
At the same time, the board raised the quarterly base dividend by 7.3% to $1.18 per share and spent $251 million to retire 1.35 million shares on the open market, up from $141 million in Q2. Notably, the company bought zero shares from its major shareholder SGF this quarter. What to watch: fourth-quarter debt redemptions after $73 million of early Q4 share buybacks, as further bond tenders will show how much cash goes to debt versus stock.
🐻 Bear Case
Viper Deals Lift Debt and Capital Spending
Chief executive Kaes Van't Hof said Viper funded its McElroy Ranch and $280 million Buckhorn mineral deals primarily with cash to "pursue accretive M&A with minimal reliance on equity". While that limited share dilution, Viper borrowed $715 million net during the quarter, pushing its net debt up 48.3% from June to $2.40 billion.
Because Diamondback consolidates Viper on its balance sheet, total consolidated net debt rose by $513 million in Q3 to $12.82 billion, reversing second-quarter deleveraging despite $2.15 billion of free cash flow. Meanwhile, parent full-year cash capital spending was raised by about $75 million at the middle of the range to $3.95–4.00 billion, driven by higher drilling budgets.
What to watch: year-end consolidated net debt once the $280 million cash portion of the Buckhorn acquisition closes in Q4. A second straight quarterly rise in total debt would show that subsidiary deal-making is absorbing the parent's balance-sheet progress.
Oil Prices Eased While Completions Outran Drilling
Diamondback's earnings boom this year rests on high crude prices while its oil output holds near a plateau. In the third quarter, its unhedged oil price dropped 9.8% from the second quarter to $87.30 per barrel, pulling total revenue down 2.4% to $5.43 billion even as daily oil production held steady at 524.9 thousand barrels.
To keep oil output flat, the company completed 133 net wells in the quarter while drilling only 100. That drew down its inventory of drilled but uncompleted wells by 33 net locations, following a 68 net well drawdown in Q2. The fourth-quarter oil plan of 518–528 thousand barrels per day sits flat against Q3 at the middle of the range.
What to watch: the ratio of wells drilled to wells completed in the fourth quarter. By our math, the full-year footage plan leaves about 1.17 million net feet for Q4, down from 1.81 million in Q3, testing whether oil volumes hold without drawing down inventory.
Risks this quarter didn't answer
Several operational initiatives and standing governance risks from prior quarters received no new data in the earnings release, leaving their progress to be checked on the conference call or in the quarterly filing.
- Bryant Ranch power project: no update on power-purchase terms or grid approval for the planned gas-fired data center plant.
- Chemical oil recovery pilot: no performance figures for the third-quarter batch of chemical well treatments.
- SGF share purchase pact: no word on whether the right of major holder SGF to sell 3 million shares per quarter to the company will extend past December 2026.
- Water divestiture earnout: no detail on how completion targets tied to the Deep Blue water joint venture affect 2027 drilling plans.
💲 Other KPIs
Operating profit rose to 46.0% of revenue from 31.5% a year ago, an increase of 14.5 percentage points by our math. Depletion expense—the non-cash write-off of past drilling costs—dropped by 8.5 percentage points of revenue to 24.3% after first-quarter property write-downs, while lease operating costs fell 2.0 points to 10.5%.
Uncollected billings from oil and gas buyers rose 87.8% from $1,128 million at the end of 2025. That build tied up $476 million of cash during the third quarter and $1,039 million over the first nine months, causing reported operating cash flow of $2,599 million to lag pre-working-capital cash flow of $3,174 million.
The average number of diluted shares fell 3.1% from 288.8 million a year ago and 0.4% from 281.2 million last quarter. Retiring shares lifted per-share profit growth: third-quarter net income rose 57.5% from a year ago, while diluted earnings per share grew 62.1% to $5.69.
🔮 Guidance
Raised. The full-year combined production plan moved up by 15 MBOE/d to about 10.2% growth over 2025, driven by higher natural gas capture and Viper mineral deals. It is the third raise this year, and smaller than the prior two moves of +28 MBOE/d and +28 MBOE/d.
Raised. The full-year crude output target stepped up by 2 MBO/d to 5.4% annual growth. This marks the third increase this year following raises of +15 MBO/d in Q1 and +2 MBO/d in Q2.
New. The fourth-quarter plan points to 523 MBO/d of oil and 1,035 MBOE/d of total output at the middle of the range, essentially unchanged from Q3 levels. If the company's 1.3% average quarterly oil beat over the past year holds, Q4 oil would land near 530 MBO/d.
Raised. The annual capital budget rose by $75 million at the middle of the range as operated drilling and completion spending increased to $3,350–3,400 million from ~$3,310 million. By our math, that leaves $1,020 million for Q4 total spending and $865 million for operated drilling.
New. Planned fourth-quarter capital outlays average $1,025 million at the middle of the range, matching the $1,026 million spent in the third quarter and $55 million above what the prior annual budget implied by our math.
Cut. The company narrowed its full-year field operating cost range and lowered the middle of the range by $0.075 to $6.075 per barrel equivalent after Q3 came in at $5.97.
Cut. The full-year pipeline and processing rate moved down by $0.10 per barrel equivalent for a second straight quarter, reflecting Q3 actuals of $1.32.
Unchanged. All four per-barrel overhead, depletion and interest expense ranges stayed where they were set last quarter, tracking in line with nine-month results.
Cut. The expected full-year severance and property tax rate dropped by half a percentage point after running at 5.9% of oil and gas sales in Q3.
Unchanged on annual rates, with a new Q4 cash outlay range of $500–560 million that sits $100 million above the third-quarter plan's range.
Raised. The full-year completed well footage plan rose by 100,000 feet at the middle of the range while average well length held steady. By our math, 9M completions of 5.23 million feet leave about 1.17 million feet for Q4.
Raised. Viper lifted its full-year oil target by 0.88 MBO/d at the middle of the range and initiated Q4 production targets that include the September McElroy Ranch closing, the parent drop-down, and the pending Buckhorn deal.
Unchanged. Viper's unit cost and tax rate targets match its third-quarter performance, where depletion was $15.86 per barrel equivalent and the effective cash tax rate was 27.4%.
❓ Key Questions
How much gas is still exposed to Waha prices?
Unhedged gas prices turned positive at $1.12 per Mcf and Diamondback bought a 7.5% stake in the Solitude pipeline, but the release did not state whether Waha exposure has reached the 40% year-end target.
What are the costs on the Spanish Trail Barnett pad?
Diamondback doubled its Barnett drilling to 14 gross wells in Q3 and Viper spent $529 million on Barnett mineral rights, making the completion costs and initial output of the first full four-well pad critical.
Where is the hyperscaler contract for Bryant Ranch?
The earnings release gave no update on the planned West Texas gas-fired power plant or its grid application, leaving open when the company will lock in a technology customer for its stranded gas.
Will the SGF share purchase deal extend into 2027?
Diamondback bought zero shares from 26.7% holder SGF in the third quarter after buying $509 million in the first half, and the current agreement giving SGF quarterly sale rights expires on December 31, 2026.