FANG · Q4 2025 Earnings

Cautious

Diamondback Energy

Reported January 12, 2026

30-second summary

30-second take: Q4 realized oil printed at $58.00/bbl unhedged, and the hedge book delivered no help — $57.07 hedged is $0.93/bbl worse than unhedged. Against that backdrop, management used the call to introduce the Barnett as the new organic growth engine — 900 gross locations, 36 MBOE/1000ft 12-month QM versus 22 for core Midland (slide 12), full field development starting H2 2026 — explicitly replacing M&A as the growth vector. The strategic shift from "Permian consolidator" to "patient operator" to "organic re-resource via Barnett + surfactants" is now visible in the prepared narrative, and corporate oil mix will trend lower as a result.

Guidance

No forward guidance provided this quarter; unable to assess changes.

Other KPIs

Q4 FY2025

Segment	Q4 FY2025
Oil - Unhedged Realized Price	$58.00/Bbl
Oil - Hedged Realized Price	$57.07/Bbl
Natural Gas - Unhedged Realized Price	$0.03/Mcf
Natural Gas - Hedged Realized Price	$1.03/Mcf
Natural Gas Liquids - Unhedged Realized Price	$13.51/Bbl
Net Gain on Derivative Instruments	$192 million
Net Cash Received on Derivative Settlements	$73 million
Basic Weighted Average Shares Outstanding	285.789 million

Management tone

Narrative arc this quarter: the strategic story pivoted explicitly to organic resource expansion through the Barnett and surfactants, with M&A reframed from active pipeline to opportunistic option.

The Barnett went from unmentioned to centerpiece in a single quarter. Multiple Q&A exchanges anchor on it — Mehta, the William Blair line, Jayaram, Lambougeon, Brackett, and others pressed on costs, EURs, oil mix implications, and development cadence. Management disclosed 900 gross locations, a 12-month productivity premium of 60%+ on first-year oil cume vs. core, and a full-field-development start in H2 2026. The signal: management is now ready to lead with Barnett as the long-duration inventory story.

Corporate oil mix is being repositioned as an explicit trade. Case told Lambougeon: "I think generally with the Barnett becoming a bigger piece of the capital pie, oil mix will go down over time." Barnett is 67% oil (flat across the curve) vs. core 80% declining to 75%. The offset is supposed to come from improved gas realizations as new pipes come on in the 2027-2030 timeframe, and potentially data-center PPA structures. Given Q4 unhedged gas printed at $0.03/Mcf, the gas-realization offset is a bet on infrastructure and contract structure, not on basis recovery.

The prepared-remarks abdication continued. Verbatim from the call: "I hope everybody read the letter last night, a lot of good detail in there." In a quarter when realized oil printed at $58 unhedged and gas basis went to zero, the choice to deliver no opening framing is a meaningful tell — management would rather control the written record than risk extempore commentary on a deteriorating tape.

The data-center / hyperscaler conversation graduated from speculative to active. Lambougeon's exchange surfaced that Diamondback now claims "all the pieces for a very compelling project" — surface acreage, water supply via Deep Blue, upstream gas/power — and that counterparty conversations have "improved." Management is explicit that the prize is "material uplift to net gas pricing" via PPA structure. With Permian gas at $0.03/Mcf, the urgency behind this conversation is obvious. The discipline of not announcing "until it's completely binding" is the right posture, but the framing has clearly moved from optionality to active pursuit.

Q&A highlights

Neil Mehta · Goldman Sachs

What is the opportunity set in the Barnett, how much capital is being deployed in 2026, what are the potential returns, and what is the oil/gas mix?

Management highlighted a position grown organically from near-zero acres without capital raises. Barnett wells show 36 MBOE/1000 ft 12-month QM vs. 22 for core Midland. At current $1,000/ft costs, returns aren't competitive, but if costs drop to $800/ft with 60% better first-year oil cumes than core, returns become competitive. 900 gross locations identified. Full field development starting H2 2026. Oil productivity is strong; GOR profile is flatter (67% oil consistently) vs. core zones (80% declining to 75%).

36 MBOE per 1000 ft 12-month QM for Barnett vs 22 for core MidlandCurrent Barnett cost: $1,000/ft; target: $800/ft900 gross locationsBarnett oil productivity 60% better first-year cume than core

Arun Jayaram · JP Morgan Securities

What is the Barnett EUR for an average well, and how will Barnett development affect overall corporate oil mix? Also, update on surfactant pilot programs.

EUR uplift of ~50% on 12-month basis equates to roughly 75 BOE/ft for Barnett vs. 50 BOE/ft for core Midland zones. Barnett becoming larger capital allocation will reduce oil mix over time, offset by improved gas realizations from upcoming pipes (2027-2030). On surfactants: 60-well test in H2 2025 with early positive results, ~100 bbl/day average uplift at ~$500k cost per job (high-returning). Testing on production side; completion-side tests planned. Results show multi-hundred bbl/day uplift on some wells.

Barnett EUR: ~75 BOE/ft vs core 50 BOE/ft (50% uplift)Corporate oil mix will decline over time as Barnett represents larger share60-well surfactant test completed H2 2025Average 100 bbl/day uplift at ~$500k cost

Jeffrey Lambougeon · TPH and Company

What is the outlook for corporate oil mix as Barnett becomes larger part of capital allocation? Update on data center/hyperscaler opportunities?

Oil mix will decline over time as Barnett represents growing capital share, but offset by improved gas realizations. Regarding data centers: Company has 'all pieces' for compelling project (surface acreage, water supply via Deep Blue, upstream gas/power). Biggest benefit is ability to structure PPA providing material uplift to net gas pricing. Conversations with counterparties have 'improved.' Will only announce when completely binding with clear investor impact.

Corporate oil mix will trend lower due to Barnett allocationGas realizations improvement critical to offset oil mix declineData center PPAs can provide material uplift to net gas pricingSurface position, water supply, and upstream power provide full package

Bob Brackett · Bernstein Research

What is driving higher drilling/completion costs for Barnett ($1,000/ft vs. $600/ft for core)? What are solutions? Also, where do international opportunities rank strategically?

Barnett costs higher due to: (1) different drilling program—oil-based mud, extra pipe string in vertical section for de-risking; (2) larger completion jobs targeting 4 wells/section with larger simfrac to generate larger SRV; currently single/two-well pads with zipper fracs. Solutions: transition to full-scale multi-well pad development, simulfrac, continuous pumping (already proven in core). Extended laterals (15,000+ ft) will also reduce per-foot cost. International opportunities rank low strategically; Permian's long-duration inventory, Barnett, and surfactants point to staying home.

Barnett drilling: oil-based mud, extra casing string required for deriskingBarnett completions: larger jobs, 4-well pads planned, transitioning from single/zipper to simulfracExtended lateral targets: 15,000+ ft in BarnettCore Midland cost ~$510-520/ft; Barnett target $800/ft

Scott Hennelt · RBC Capital Markets

Why has Diamondback shifted from M&A-focused growth to organic resource expansion (Barnett)? What drove this strategic shift?

Consolidation in Permian has created natural 'basin champions' (independent producers like Diamondback), 'mineral champions' (Viper), and 'surface champions.' With fewer M&A opportunities, management decided to invest more capital improving existing resource base through initiatives like Barnett and surfactants. Company remains open to M&A but deals are 'fewer and further between.' Management monitors all basin deals.

Consolidation trend has reduced available M&A targetsIndustry moving toward specialized champions: independent producers, mineral companies, surface companiesShift to organic growth: Barnett, surfactants, cost reductionsM&A remains option but opportunities limited

Answers to last quarter's watch list

Asset sale disclosure ($1.5B program, Epic pipeline stake, Endeavor water assets) — Not addressed in this quarter's Q&A. The strategic story this quarter pivoted to Barnett and organic growth; the asset-sale program was not surfaced. Status: Not resolved.

2026 maintenance capex confirmation — Case referenced a $3.75B total budget with $150M allocated to the Barnett, and noted Q1 and Q2 2026 CapEx will run toward the low end of the quarterly average, with a potential step-down in the back half if Barnett well costs and surfactant results trend favorably. Full field development of the Barnett starts H2 2026. Status: Partially addressed.

Continuous pumping fleet rollout — Addressed via the John Freeman and Brackett exchanges: leading-edge continuous-pumping fleets are averaging 4,500 ft/day completed, with results above 5,500 ft/day observed. The technique is named as one of the levers to take Barnett cost from $1,000/ft toward $800/ft. Status: Resolved positively.

Reinvestment rate at the strip — Not directly addressed at current price levels. With Q4 oil at $58 unhedged and the corporate strategy pivoting to organic growth investment via Barnett, the reinvestment rate is almost certainly stepping up, but management did not quantify. Status: Not resolved.

Share count trajectory — Basic shares were 285.789M in Q4. Buyback execution detail beyond the share-count print was not in the 8-K. Status: Partially addressed.

Yellow-to-green light timing — Case described the company as still in a "quasi-yellow light" posture: oil production is the input, CapEx flexes down if the macro allows and holds steady otherwise. Management's response to weaker realizations is to pivot the strategic story to a new organic growth play (Barnett) rather than flex activity down materially. Status: Partially resolved — still yellow, with a strategic offset.

What to watch into next quarter

Barnett 2026 capital allocation and total capex: $150M Barnett within a $3.75B total budget was disclosed; H2 2026 full field development was confirmed. Watch whether the back-half CapEx step-down Case telegraphed materializes, and whether Barnett's share of capital grows.

Barnett cost trajectory toward $800/ft: $1,000/ft today, $800/ft target via multi-well pads, simulfrac, continuous pumping, and 15,000+ ft laterals. First Q1 FY2026 print on Barnett well costs is the key data point — if costs are still north of $950/ft, the development case slips.

Permian gas realization recovery or data-center PPA announcement: $0.03/Mcf unhedged is unsustainable as a long-run base case. Either basis recovers as 2027+ pipes get firmer commitment, or a data-center / hyperscaler PPA gets announced "completely binding" per Lambougeon's exchange.

Asset sale program closure: Without a Q1 FY2026 update on per-transaction proceeds, the $1.5B program should be assumed delayed or rescoped.

Hedge book repositioning on oil: Hedged oil printed BELOW unhedged this quarter ($57.07 vs. $58.00) — the structure is hurting on oil. Watch the next disclosure of hedge positions for the 2026 book: does management let the bad hedges roll off and reprice at the strip, or are they extended?

Surfactant program scale-up: 60-well pilot in H2 2025 delivered ~100 bbl/day average uplift at ~$500k cost. Watch whether 2026 disclosure surfaces a count of wells treated and an annualized production uplift — a few hundred wells at these economics is a real production lever not in any guidance.

Sources

Diamondback Energy Form 8-K (Item 2.02 interim disclosure of Q4 2025 realized prices and derivatives), January 12, 2026: https://www.sec.gov/Archives/edgar/data/1539838/000153983826000003/fang-20260112.htm
Diamondback Energy Q4 FY2025 earnings call Q&A (no prepared remarks delivered; analyst Q&A exchanges with Mehta, the William Blair line, Lambougeon, Jungworth, Jayaram, Brackett, Freeman, Whitfield, Ackermine, McCurdy, Leggett)

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