Open the filing on EDGARDIAMONDBACK ENERGY, INC. ANNOUNCES THIRD QUARTER 2025 FINANCIAL AND OPERATING RESULTS
Midland, TX (November 3, 2025) - Diamondback Energy, Inc. (NASDAQ: FANG) (“Diamondback,” “we,” “our” or the “Company”) today announced financial and operating results for the third quarter ended September 30, 2025.
THIRD QUARTER 2025 HIGHLIGHTS
- Average oil production of 503.8 MBO/d (942.9 MBOE/d)
- Net cash provided by operating activities of $2.4 billion; Operating Cash Flow Before Working Capital Changes of $2.5 billion
- Cash capital expenditures of $774 million
- Free Cash Flow of $1.8 billion; Adjusted Free Cash Flow of $1.8 billion
- Declared Q3 2025 base cash dividend of $1.00 per share payable on November 20, 2025; implies a 2.8% annualized yield based on October 31, 2025 closing share price of $143.19
- Repurchased 4,286,080 shares of common stock for approximately $603 million (at a weighted average price of $140.70 per share excluding excise tax)
- Total return of capital of $892 million; represents 50% of Adjusted Free Cash Flow from stock repurchases and the declared Q3 2025 base dividend
- As previously announced, Viper Energy, Inc. ("Viper"), a subsidiary of Diamondback, closed the acquisition of Sitio Royalties Corp. ("Sitio") on August 19th
RECENT HIGHLIGHTS
- On October 1st, closed the previously announced divestiture of Environmental Disposal Systems, LLC to Deep Blue Midland Basin LLC (“Deep Blue”); Diamondback retained its 30% equity ownership in Deep Blue and received $694 million upfront cash proceeds; additionally, Diamondback has the potential to earn up to $200 million in contingent consideration based on the achievement of certain completion thresholds for the years 2026 through 2028
- On October 31st, closed the previously announced divestiture of the Company's 27.5% equity interest in EPIC Crude Holdings, LP ("EPIC Crude") and received $504 million upfront cash proceeds; additionally, Diamondback has the potential to earn $96 million in contingent consideration should a capacity expansion of EPIC Crude be formally sanctioned before year-end 2027
- Repurchased 610,996 shares of common stock in Q4 2025 (to date) for $87 million (at a weighted average price of $143.21 per share excluding excise tax )
NON-GAAP DISCLOSURES
For a definition of Operating Cash Flow Before Working Capital Changes, Free Cash Flow, Adjusted Free Cash Flow, Adjusted Net Income, Adjusted EBITDA, Adjusted Net Income per Diluted Share, Net Debt and reconciliations of such non-GAAP financial metrics to their respective most directly comparable GAAP metrics, please see “Non-GAAP Financial Measures” below.
- Repurchased $203 million in senior notes due 2051 & 2052 at 82.3% of par (~$167 million) in Q4 2025 (to date)
UPDATED 2025 GUIDANCE HIGHLIGHTS
- Increasing full year oil production guidance to 495 - 498 MBO/d and increasing annual BOE guidance to 910 - 920 MBOE/d
- Narrowing full year cash capital expenditures to $3.45 - $3.55 billion; unchanged at the midpoint from August update
- The Company expects to drill 445 - 465 gross (412 - 430 net) wells and complete between 510 - 520 gross (471 - 481 net) wells with an average lateral length of approximately 11,500 feet in 2025
- Q4 2025 oil production guidance of 505 - 515 MBO/d (927 - 963 MBOE/d)
- Q4 2025 cash capital expenditures guidance of $875 - $975 million
OPERATIONS UPDATE
The following tables provide a summary of Diamondback’s key operational updates for the quarter:
Wells Drilled and Completed:
| Three Months Ended September 30, 2025 | Nine Months Ended September 30, 2025 |
|---|
| Drilled | Completed | Drilled | Completed |
|---|
| Area: | Gross | Net | Gross | Net | Gross | Net | Gross | Net |
| Midland Basin | 107 | 97 | 137 | 127 | 352 | 326 | 361 | 342 |
| Delaware Basin | 1 | 1 | - | - | 4 | 4 | 15 | 13 |
| Total | 108 | 98 | 137 | 127 | 356 | 330 | 376 | 355 |
Gross Wells Drilled and Completed By Zone:
| Three Months Ended September 30, 2025 | Nine Months Ended September 30, 2025 |
|---|
| Number of Wells Drilled | Number of Wells Completed | Number of Wells Drilled | Number of Wells Completed |
|---|
| Midland Basin: | | | | |
| Upper Spraberry | 1 | 3 | 6 | 13 |
| Middle Spraberry | 7 | 11 | 24 | 32 |
| Jo Mill | 19 | 26 | 63 | 54 |
| Lower Spraberry | 19 | 28 | 73 | 77 |
| Dean | 1 | 10 | 13 | 22 |
| Wolfcamp A | 28 | 27 | 73 | 66 |
| Wolfcamp B | 25 | 27 | 83 | 80 |
| Wolfcamp D | 4 | 1 | 9 | 7 |
| Barnett | 3 | 4 | 8 | 10 |
| Midland Basin Total | 107 | 137 | 352 | 361 |
| Delaware Basin: | | | | |
| 2nd Bone Spring | - | - | - | 2 |
| 3rd Bone Spring | 1 | - | 3 | 8 |
| Wolfcamp A | - | - | 1 | 5 |
| Delaware Basin Total | 1 | - | 4 | 15 |
| Total Company Operated | 108 | 137 | 356 | 376 |
| Average Completed Lateral Length (in feet) | | 11,020 | | 12,060 |
Realized Average Prices:
| Three Months Ended |
|---|
| September 30, 2025 | June 30, 2025 | September 30, 2024 |
|---|
| Average Prices: | | | |
| Oil ($ per Bbl) | $64.60 | $63.23 | $73.13 |
| Natural gas ($ per Mcf) | $0.75 | $0.88 | $(0.26) |
| Natural gas liquids ($ per Bbl) | $17.28 | $18.13 | $17.70 |
| Combined ($ per BOE) | $39.73 | $39.61 | $44.80 |
| Oil, hedged ($ per Bbl) | $63.70 | $62.34 | $72.32 |
| Natural gas, hedged ($ per Mcf) | $1.75 | $1.45 | $0.60 |
| Natural gas liquids, hedged ($ per Bbl) | $17.28 | $18.13 | $17.70 |
| Average price, hedged ($ per BOE) | $40.58 | $39.89 | $45.43 |
(1) Hedged prices reflect the effect of our commodity derivative transactions on our average sales prices and include gains and losses on cash settlements for matured commodity derivatives, which we do not designate for hedge accounting. Hedged prices exclude gains or losses resulting from the early settlement of commodity derivative contracts.
Average Costs per BOE:
| Three Months Ended |
|---|
| September 30, 2025 | June 30, 2025 | September 30, 2024 |
|---|
| Lease operating expenses | $5.65 | $5.26 | $6.01 |
| Production and ad valorem taxes | 2.44 | 2.56 | 2.91 |
| Gathering, processing and transportation expense | 1.41 | 1.73 | 1.94 |
| General and administrative - cash component | 0.55 | 0.55 | 0.63 |
| Total operating expense - cash | $10.05 | $10.10 | $11.49 |
FINANCIAL UPDATE
Earnings Attributable to Diamondback Energy, Inc.:
| Three Months Ended September 30, 2025 |
|---|
| (in millions, except per share amounts) |
|---|
| Net income (loss) attributable to Diamondback Energy, Inc. | $1,018 |
| Earnings (loss) per common share attributable to Diamondback Energy, Inc. - Diluted | $3.51 |
| Adjusted net income | $895 |
| Adjusted net income per common share - Diluted | $3.08 |
(1) The Company’s earnings (loss) per diluted share amount has been computed using the two-class method in accordance with GAAP. The two-class method is an earnings allocation which reflects the respective ownership among holders of common stock and participating securities. Diluted earnings per share using the two-class method is calculated as (i) net income attributable to Diamondback Energy, Inc, (ii) less the reallocation of $4 million in earnings attributable to participating securities, (iii) divided by diluted weighted average common shares outstanding for the respective periods.
Capital Expenditures:
| Three Months Ended September 30, | Nine Months Ended September 30, |
|---|
| 2025 | 2024 | 2025 | 2024 |
|---|
| (in millions) |
|---|
| Operated drilling and completion additions to oil and natural gas properties | $632 | | $631 | | $2,203 | | $1,785 | |
| Capital workovers, non-operated additions to oil and natural gas properties and science | 94 | | 2 | | 205 | | 13 | |
| Infrastructure, environmental and midstream additions | 48 | | 55 | | 172 | | 136 | |
| Total | $774 | | $688 | | $2,580 | | $1,934 | |
Adjusted EBITDA and Free Cash Flow - Non-GAAP:
| Three Months Ended September 30, 2025 | Nine Months Ended September 30, 2025 |
|---|
| (in millions) |
|---|
| Net income (loss) attributable to Diamondback Energy, Inc. | $1,018 | $3,122 |
| Consolidated Adjusted EBITDA | $2,638 | $8,027 |
| Adjusted EBITDA attributable to Diamondback Energy, Inc. | $2,408 | $7,520 |
| Net cash provided by operating activities | $2,383 | $6,415 |
| Free Cash Flow | $1,760 | $4,547 |
| Adjusted Free Cash Flow | $1,792 | $4,709 |
Debt & Liquidity:
| September 30, 2025 |
|---|
| (in millions) |
|---|
| Standalone cash | $106 |
| Borrowings outstanding under the credit facility | $175 |
| Remaining availability under the credit facility | $2,325 |
| Total liquidity | $2,431 |
| Consolidated total debt | $16,432 |
| Consolidated total net debt | $15,893 |
RETURN OF CAPITAL UPDATE
Diamondback announced today that the Company’s Board of Directors (the "Board") declared a base cash dividend of $1.00 per common share for the third quarter of 2025 payable on November 20, 2025, to stockholders of record at the close of business on November 13, 2025.
On July 31, 2025, Diamondback’s Board approved a $2.0 billion increase to the share repurchase authorization, bringing total capacity to $8.0 billion (excluding excise tax), with $3.0 billion remaining as of October 31, 2025. The Company expects to continue repurchases opportunistically using cash on hand, free cash flow and potential asset sale proceeds. The program has no time limit and may be suspended, modified or discontinued at the Board’s discretion. Repurchases may be executed in privately negotiated or open-market transactions, consistent with Rule 10b-18 under the Securities Exchange Act of 1934, as amended, and will be subject to market conditions, applicable regulatory and legal requirements and other factors. All shares repurchased will be retired.
The table below summarizes Diamondback’s return of capital program, including dividends and share repurchases, with future actions subject to Board approval.
| Q3 2025 | Q4 2025 to date | Cumulative |
|---|
| (in millions, except per share amounts, shares in thousands) |
|---|
| Base dividend | $1.00 | | |
| Shares repurchased | 4,286 | 611 | 36,129 |
| Weighted average repurchase price | $140.70 | $143.21 | $138.08 |
| Total repurchase cost | $603 | $87 | $4,989 |
| Total return of capital | $892 | | |
| Return of capital % free cash flow | 51% | | |
| Return of capital % adjusted free cash flow | 50% | | |
FULL YEAR 2025 GUIDANCE
Below is Diamondback's updated guidance for the full year 2025, which includes fourth quarter production, cash tax and capital guidance.
| 2025 Guidance | 2025 Guidance |
|---|
| Diamondback Energy, Inc. | Viper Energy, Inc. |
|---|
| 2025 Net production - MBOE/d | 910 - 920 (from 890 - 910) | 92.8 - 93.5 |
| 2025 Oil production - MBO/d | 495 - 498 (from 485 - 492) | 48.8 - 49.0 |
| Q4 2025 Oil production - MBO/d (total - MBOE/d) | 505 - 515 (927 - 963) | 65.0 - 67.0 (124.0 - 128.0) |
| Unit costs ($/BOE) | | |
| Lease operating expenses, including workovers | $5.40 - $5.70 (from $5.30 - $5.70) | |
| G&A | | |
| Cash G&A | $0.60 - $0.75 | $0.80 - $1.00 |
| Non-cash equity-based compensation | $0.25 - $0.35 | $0.10 - $0.20 |
| DD&A | $14.50 - $15.50 | $16.75 - $17.25 |
| Interest expense (net of interest income) | $0.60 - $0.80 | $2.50 - $3.00 |
| Gathering, processing and transportation | $1.45 - $1.60 (from $1.60 - $1.75) | |
| Production and ad valorem taxes (% of revenue) | ~7% | ~7% |
| Corporate tax rate (% of pre-tax income) | 23% | |
| Cash tax rate (% of pre-tax income) | 15% - 18% | 21% - 23% |
| Q4 2025 Cash taxes ($ - million)(2) (3) | $270 - $350 | $13 - $18 |
| Capital Budget ($ - million) | | |
| Operated drilling and completion | $2,925 - $2,950 (from $2,850 - $2,950) | |
| Capital workovers, non-operated properties and science | $300 - $350 (from $250 - $300) | |
| Infrastructure, environmental and midstream | $225 - $250 (from $300 - $350) | |
| 2025 Total capital expenditures | $3,450 - $3,550 (from $3,400 - $3,600) | |
| Q4 2025 Capital expenditures | $875 - $975 | |
| Gross horizontal wells drilled (net) | 445 - 465 (412 - 430) (from 425 - 450 (395 - 418)) | |
| Gross horizontal wells completed (net) | 510 - 520 (471 - 481) (from 490 - 515 (458 - 482)) | |
| Average lateral length (Ft.) | ~11,500' | |
| FY 2025 Midland Basin well costs per lateral foot | $550 - $580 | |
| FY 2025 Delaware Basin well costs per lateral foot | $860 - $910 | |
| Midland Basin completed net lateral feet (%) | ~95% | |
| Delaware Basin completed net lateral feet (%) | ~5% | |
Pre-tax income attributable to the Company is a non-GAAP measure. We are not able to forecast the most directly comparable GAAP measure - Income (loss) before income taxes - due to high variability and difficulty in predicting certain items that affect Income (loss) before income taxes, such as future commodity prices, pace of and costs of developing, producing and operating our interests in oil and natural gas properties, future changes in interest rates and various other business factors impacting our financial results.
Includes approximately $175 million tax impact from asset divestitures in the fourth quarter.
Includes estimated favorable impact on the year-to-date period of tax legislation enacted in the third quarter.
CONFERENCE CALL
Diamondback will host a conference call and webcast for investors and analysts to discuss its results for the third quarter of 2025 on Tuesday, November 4, 2025 at 8:00 a.m. CT. Access to the webcast, and replay which will be available following the call, may be found here. The live webcast of the earnings conference call will also be available via Diamondback’s website at www.diamondbackenergy.com under the “Investor Relations” section of the site.
About Diamondback Energy, Inc.
Diamondback is an independent oil and natural gas company headquartered in Midland, Texas focused on the acquisition, development, exploration and exploitation of unconventional, onshore oil and natural gas reserves primarily in the Permian Basin in West Texas. For more information, please visit www.diamondbackenergy.com.
Forward-Looking Statements
Forward-looking statements notice
This news release contains “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act, which involve risks, uncertainties, and assumptions. All statements, other than statements of historical fact, including statements regarding Diamondback’s: future performance; business strategy; future operations (including drilling plans and capital plans); estimates and projections of revenues, losses, costs, expenses, returns, cash flow, and financial position; reserve estimates and its ability to replace or increase reserves; anticipated benefits or other effects of strategic transactions including the Endeavor acquisition, Double Eagle acquisition, 2025 drop down and Sitio acquisition and other acquisitions or divestitures; and plans and objectives of management (including plans for future cash flow from operations and for executing environmental strategies) are forward-looking statements. When used in this news release, the words “aim,” “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,” “intend,” “may,” “model,” “outlook,” “plan,” “positioned,” “potential,” “predict,” “project,” “seek,” “should,” “target,” “will,” “would,” and similar expressions (including the negative of such terms) as they relate to Diamondback are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Although Diamondback believes that the expectations and assumptions reflected in its forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond Diamondback’s control. Accordingly, forward-looking statements are not guarantees of future performance and Diamondback’s actual outcomes could differ materially from what Diamondback has expressed in its forward-looking statements.
Factors that could cause the outcomes to differ materially include (but are not limited to) the following: changes in supply and demand levels for oil, natural gas and natural gas liquids and the resulting impact on the price for those commodities; the impact of public health crises, including epidemic or pandemic diseases and any related company or government policies or actions; actions taken by the members of OPEC and Russia affecting the production and pricing of oil, as well as other domestic and global political, economic, or diplomatic developments; changes in general economic, business or industry conditions, including changes in foreign currency exchange rates, interest rates and inflation rates, instability in the financial sector; regional supply and demand factors, including delays, curtailment delays or interruptions of production, or governmental orders, rules or regulations that impose production limits; federal and state legislative and regulatory initiatives relating to hydraulic fracturing, including the effect of existing and future laws and governmental regulations; physical and transition risks relating to climate change; restrictions on the use of water, including limits on the use of produced water and a moratorium on new produced water well permits recently imposed by the Texas Railroad Commission in an effort to control induced seismicity in the Permian Basin; significant declines in prices for oil, natural gas, or natural gas liquids, which could require recognition of significant impairment charges; changes in U.S. energy, environmental, monetary and trade policies, including with respect to tariffs or other trade barriers and any resulting trade tensions; conditions in the capital, financial and credit markets, including the availability and pricing of capital for drilling and development operations and our environmental and social responsibility projects; challenges with employee retention and an increasingly competitive labor market; changes in availability or cost of rigs, equipment, raw materials, supplies and oilfield services; changes in safety, health, environmental, tax and other regulations or requirements (including those addressing air emissions, water management, or the impact of global climate change); security threats, including cybersecurity threats and disruptions to our business and operations from breaches of our information technology systems, or from breaches of information technology systems of third parties with whom we transact business; lack of, or disruption in, access to adequate and reliable transportation, processing, storage and other facilities for our oil, natural gas and natural gas liquids; failures or delays in achieving expected reserve or production levels from existing and future oil and natural gas developments, including due to operating hazards, drilling risks, or the inherent uncertainties in predicting reserve and reservoir performance; difficulty in obtaining necessary approvals and permits; severe weather conditions and natural disasters; acts of war or terrorist acts and the governmental or military response thereto; changes in the financial strength of counterparties to our credit agreement and hedging contracts; changes in our credit rating; risks related to the recently completed Endeavor acquisition, Double Eagle acquisition, 2025 drop down and Sitio acquisition; those other risks described in Part I, Item 1A of Diamondback’s Annual Report on Form 10-K, filed with the SEC on February 26, 2025, and those risks disclosed in its subsequent filings on Forms 10-Q and 8-K, which can be obtained free of charge on the SEC’s website at http://www.sec.gov and Diamondback’s website at www.diamondbackenergy.com/investors.
In light of these factors, the events anticipated by Diamondback’s forward-looking statements may not occur at the time anticipated or at all. Moreover, Diamondback operates in a very competitive and rapidly changing environment and new risks emerge from time to time. Diamondback cannot predict all risks, nor can it assess the impact of all factors on its business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those anticipated by any forward-looking statements it may make. Accordingly, you should not place undue reliance on any forward-looking statements. All forward-looking statements speak only as of the date of this release or, if earlier, as of the date they were made. Diamondback does not intend to, and disclaims any obligation to, update or revise any forward-looking statements unless required by applicable law.
| September 30, | December 31, |
|---|
| 2025 | 2024 |
|---|
| Diamondback Energy, Inc. |
| Condensed Consolidated Balance Sheets |
| (unaudited, in millions, except share amounts) |
| Assets | | |
| Current assets: | | |
| Cash and cash equivalents ($53 million and $27 million related to Viper) | $159 | | $161 | |
| Restricted cash ($390 million and $ - million related to Viper) | 393 | | 3 | |
| Accounts receivable: | | |
| Joint interest and other, net | 345 | | 198 | |
| Oil and natural gas sales, net ($290 million and $149 million related to Viper) | 1,280 | | 1,387 | |
| Inventories | 86 | | 116 | |
| Derivative instruments | 174 | | 168 | |
| Prepaid expenses and other current assets | 144 | | 77 | |
| Total current assets | 2,581 | | 2,110 | |
| Property and equipment: | | |
| Oil and natural gas properties, full cost method of accounting ($24,498 million and $22,666 million excluded from amortization at September 30, 2025, and December 31, 2024, respectively) ($14,589 million and $5,713 million related to Viper and $5,275 million and $2,180 million excluded from amortization related to Viper) | 94,309 | | 82,240 | |
| Other property, equipment and land | 1,019 | | 1,440 | |
| Accumulated depletion, depreciation, amortization and impairment ($1,454 million and $1,081 million related to Viper) | (22,795) | | (19,208) | |
| Property and equipment, net | 72,533 | | 64,472 | |
| Funds held in escrow | 17 | | 1 | |
| Equity method investments | 362 | | 375 | |
| Assets held for sale | 505 | | - | |
| Derivative instruments | 1 | | 2 | |
| Deferred income taxes, net ($ - million and $185 million related to Viper) | - | | 173 | |
| Other assets | 214 | | 159 | |
| Total assets | $76,213 | | $67,292 | |
| Liabilities and Stockholders’ Equity | | |
| Current liabilities: | | |
| Accounts payable - trade | $426 | | $253 | |
| Accrued capital expenditures | 846 | | 690 | |
| Current maturities of debt ($380 million and $ - million related to Viper) | 394 | | 900 | |
| Other accrued liabilities | 1,000 | | 1,020 | |
| Revenues and royalties payable | 1,433 | | 1,491 | |
| Derivative instruments | 10 | | 43 | |
| Income taxes payable | 33 | | 414 | |
| Total current liabilities | 4,142 | | 4,811 | |
| Long-term debt ($2,241 million and $1,083 million related to Viper) | 15,848 | | 12,075 | |
| Derivative instruments | 106 | | 106 | |
| Asset retirement obligations | 584 | | 573 | |
| Deferred income taxes | 9,877 | | 9,826 | |
| Other long-term liabilities | 22 | | 39 | |
| Total liabilities | 30,579 | | 27,430 | |
| Stockholders’ equity: | | |
| Common stock, $0.01 par value; 800,000,000 shares authorized; 286,876,206 and 290,984,373 shares issued and outstanding at September 30, 2025, and December 31, 2024, respectively | 3 | | 3 | |
| Additional paid-in capital | 32,606 | | 33,501 | |
| Retained earnings (accumulated deficit) | 6,486 | | 4,238 | |
| Accumulated other comprehensive income (loss) | (7) | | (6) | |
| Total Diamondback Energy, Inc. stockholders’ equity | 39,088 | | 37,736 | |
| Non-controlling interest | 6,546 | | 2,126 | |
| Total equity | 45,634 | | 39,862 | |
| Total liabilities and stockholders’ equity | $76,213 | | $67,292 | |
| Three Months Ended September 30, | Nine Months Ended September 30, |
|---|
| 2025 | 2024 | 2025 | 2024 |
|---|
| Diamondback Energy, Inc. |
| Condensed Consolidated Statements of Operations |
| (unaudited, $ in millions except per share data, shares in thousands) |
| Revenues: | | | | |
| Oil, natural gas and natural gas liquid sales | $3,447 | | $2,354 | | $10,420 | | $6,629 | |
| Sales of purchased oil | 459 | | 282 | | 1,168 | | 698 | |
| Other operating income | 18 | | 9 | | 62 | | 28 | |
| Total revenues | 3,924 | | 2,645 | | 11,650 | | 7,355 | |
| Costs and expenses: | | | | |
| Lease operating expenses | 490 | | 316 | | 1,338 | | 825 | |
| Production and ad valorem taxes | 212 | | 153 | | 654 | | 413 | |
| Gathering, processing and transportation | 122 | | 102 | | 378 | | 261 | |
| Purchased oil expense | 455 | | 280 | | 1,168 | | 696 | |
| Depreciation, depletion, amortization and accretion | 1,286 | | 742 | | 3,649 | | 1,694 | |
| General and administrative expenses | 70 | | 49 | | 210 | | 141 | |
| Merger and transaction expenses | 17 | | 258 | | 94 | | 273 | |
| Other operating expenses | 36 | | 35 | | 111 | | 68 | |
| Total costs and expenses | 2,688 | | 1,935 | | 7,602 | | 4,371 | |
| Income (loss) from operations | 1,236 | | 710 | | 4,048 | | 2,984 | |
| Other income (expense): | | | | |
| Interest expense, net | (70) | | (18) | | (166) | | (101) | |
| Other income (expense), net | 108 | | 89 | | 133 | | 87 | |
| Gain (loss) on derivative instruments, net | 120 | | 131 | | 149 | | 101 | |
| Gain (loss) on extinguishment of debt | (32) | | - | | 23 | | 2 | |
| Income (loss) from equity investments, net | 8 | | 6 | | 20 | | 23 | |
| Total other income (expense), net | 134 | | 208 | | 159 | | 112 | |
| Income (loss) before income taxes | 1,370 | | 918 | | 4,207 | | 3,096 | |
| Provision for (benefit from) income taxes | 287 | | 210 | | 894 | | 685 | |
| Net income (loss) | 1,083 | | 708 | | 3,313 | | 2,411 | |
| Net income (loss) attributable to non-controlling interest | 65 | | 49 | | 191 | | 147 | |
| Net income (loss) attributable to Diamondback Energy, Inc. | $1,018 | | $659 | | $3,122 | | $2,264 | |
| Earnings (loss) per common share: | | | | |
| Basic | $3.51 | | $3.19 | | $10.71 | | $12.00 | |
| Diluted | $3.51 | | $3.19 | | $10.71 | | $12.00 | |
| Weighted average common shares outstanding: | | | | |
| Basic | | 288,826 | | 204,730 | | 290,188 | | 187,253 |
| Diluted | | 288,826 | | 204,730 | | 290,188 | | 187,253 |
| Three Months Ended September 30, | Nine Months Ended September 30, |
|---|
| 2025 | 2024 | 2025 | 2024 |
|---|
| Diamondback Energy, Inc. |
| Condensed Consolidated Statements of Cash Flows |
| (unaudited, in millions) |
| Cash flows from operating activities: | | | | |
| Net income (loss) | $1,083 | | $708 | | $3,313 | | $2,411 | |
| Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities: | | | | |
| Provision for (benefit from) deferred income taxes | 253 | | 51 | | 235 | | 180 | |
| Depreciation, depletion, amortization and accretion | 1,286 | | 742 | | 3,649 | | 1,694 | |
| (Gain) loss on extinguishment of debt | 32 | | - | | (23) | | (2) | |
| (Gain) loss on derivative instruments, net | (120) | | (131) | | (149) | | (101) | |
| Cash received (paid) on settlement of derivative instruments | 60 | | (4) | | 108 | | (36) | |
| (Income) loss from equity investment, net | (8) | | (6) | | (20) | | (23) | |
| Equity-based compensation expense | 22 | | 16 | | 61 | | 49 | |
| Other | (74) | | 20 | | (47) | | 77 | |
| Changes in operating assets and liabilities: | | | | |
| Accounts receivable | (22) | | 106 | | 138 | | 61 | |
| Income tax receivable | - | | - | | 3 | | 12 | |
| Prepaid expenses and other current assets | (49) | | (11) | | (65) | | 78 | |
| Accounts payable and accrued liabilities | 28 | | (395) | | (355) | | (490) | |
| Income taxes payable | (206) | | (36) | | (515) | | (51) | |
| Revenues and royalties payable | 58 | | 95 | | 28 | | 109 | |
| Other | 40 | | 54 | | 54 | | 104 | |
| Net cash provided by (used in) operating activities | 2,383 | | 1,209 | | 6,415 | | 4,072 | |
| Cash flows from investing activities: | | | | |
| Additions to oil and natural gas properties | (774) | | (688) | | (2,580) | | (1,934) | |
| Property acquisitions | (1,536) | | (7,791) | | (5,411) | | (7,994) | |
| Proceeds from sale of assets | 257 | | 207 | | 314 | | 459 | |
| Other | (6) | | 106 | | (14) | | 103 | |
| Net cash provided by (used in) investing activities | (2,059) | | (8,166) | | (7,691) | | (9,366) | |
| Cash flows from financing activities: | | | | |
| Proceeds under term loan agreements | 500 | | 1,000 | | 2,000 | | 1,000 | |
| Repayments under term loan agreements | - | | - | | (900) | | - | |
| Proceeds from borrowings under credit facilities | 2,300 | | 1,011 | | 8,222 | | 1,185 | |
| Repayments under credit facilities | (2,885) | | (1,073) | | (8,148) | | (1,333) | |
| Proceeds from senior notes | 1,600 | | - | | 2,800 | | 5,500 | |
| Repayment of senior notes | (428) | | - | | (672) | | (25) | |
| Repurchased shares under buyback program | (603) | | (515) | | (1,576) | | (557) | |
| Proceeds from partial sale of investment in Viper Energy, Inc. | - | | - | | - | | 451 | |
| Net proceeds from Viper’s issuance of common stock | - | | 476 | | 1,232 | | 476 | |
| Dividends paid to stockholders | (289) | | (416) | | (870) | | (1,316) | |
| Dividends to non-controlling interest | (78) | | (59) | | (255) | | (157) | |
| Other | (110) | | (5) | | (169) | | (142) | |
| Net cash provided by (used in) financing activities | 7 | | 419 | | 1,664 | | 5,082 | |
| Net increase (decrease) in cash, cash equivalents and restricted cash | 331 | | (6,538) | | 388 | | (212) | |
| Cash, cash equivalents and restricted cash at beginning of period | 221 | | 6,911 | | 164 | | 585 | |
| Cash, cash equivalents and restricted cash at end of period | $552 | | $373 | | $552 | | $373 | |
| Three Months Ended |
|---|
| September 30, 2025 | June 30, 2025 | September 30, 2024 |
|---|
| Diamondback Energy, Inc. |
| Selected Operating Data |
| (unaudited) |
| Production Data: | | | |
| Oil (MBbls) | 46,345 | 45,108 | 29,537 |
| Natural gas (MMcf) | 115,353 | 110,119 | 66,519 |
| Natural gas liquids (MBbls) | 21,180 | 20,248 | 11,918 |
| Combined volumes (MBOE) | 86,751 | 83,709 | 52,541 |
| Daily oil volumes (BO/d) | 503,750 | 495,692 | 321,054 |
| Daily combined volumes (BOE/d) | 942,946 | 919,879 | 571,098 |
| Average Prices: | | | |
| Oil ($ per Bbl) | $64.60 | $63.23 | $73.13 |
| Natural gas ($ per Mcf) | $0.75 | $0.88 | $(0.26) |
| Natural gas liquids ($ per Bbl) | $17.28 | $18.13 | $17.70 |
| Combined ($ per BOE) | $39.73 | $39.61 | $44.80 |
| Oil, hedged ($ per Bbl) | $63.70 | $62.34 | $72.32 |
| Natural gas, hedged ($ per Mcf) | $1.75 | $1.45 | $0.60 |
| Natural gas liquids, hedged ($ per Bbl) | $17.28 | $18.13 | $17.70 |
| Average price, hedged ($ per BOE) | $40.58 | $39.89 | $45.43 |
| Average Costs per BOE: | | | |
| Lease operating expenses | $5.65 | $5.26 | $6.01 |
| Production and ad valorem taxes | 2.44 | 2.56 | 2.91 |
| Gathering, processing and transportation expense | 1.41 | 1.73 | 1.94 |
| General and administrative - cash component | 0.55 | 0.55 | 0.63 |
| Total operating expense - cash | $10.05 | $10.10 | $11.49 |
| General and administrative - non-cash component | $0.25 | $0.25 | $0.30 |
| Depreciation, depletion, amortization and accretion | $14.82 | $15.12 | $14.12 |
| Interest expense, net | $0.81 | $0.67 | $0.34 |
(1)Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.
(2)Hedged prices reflect the effect of our commodity derivative transactions on our average sales prices and include gains and losses on cash settlements for matured commodity derivatives, which we do not designate for hedge accounting. Hedged prices exclude gains or losses resulting from the early settlement of commodity derivative contracts.
NON-GAAP FINANCIAL MEASURES
ADJUSTED EBITDA
Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. The Company defines Adjusted EBITDA as net income (loss) attributable to Diamondback Energy, Inc., plus net income (loss) attributable to non-controlling interest ("net income (loss)") before non-cash (gain) loss on derivative instruments, net, interest expense, net, depreciation, depletion, amortization and accretion, depreciation and interest expense related to equity method investments, (gain) loss on extinguishment of debt, non-cash equity-based compensation expense, capitalized equity-based compensation expense, merger and transaction expenses, other non-cash transactions and provision for (benefit from) income taxes. Adjusted EBITDA is not a measure of net income as determined by United States generally accepted accounting principles ("GAAP"). Management believes Adjusted EBITDA is useful because the measure allows it to evaluate the Company’s operating performance and compare the results of its operations from period to period without regard to its financing methods or capital structure. The Company excludes the items listed above from net income (loss) to determine Adjusted EBITDA because these amounts can vary substantially from company to company within its industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Further, the Company excludes the effects of significant transactions that may affect earnings but are unpredictable in nature, timing and amount, although they may recur in different reporting periods. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of the Company’s operating performance. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets. The Company’s computation of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies or to such measure in our credit facility or any of our other contracts.
The following tables present a reconciliation of the GAAP financial measure of net income (loss) attributable to Diamondback Energy, Inc. to the non-GAAP financial measure of Adjusted EBITDA:
| Three Months Ended September 30, 2025 | Nine Months Ended September 30, 2025 |
|---|
| Diamondback Energy, Inc. | |
| Reconciliation of Net Income (Loss) to Adjusted EBITDA | |
| (unaudited, in millions) | |
| Net income (loss) attributable to Diamondback Energy, Inc. | $1,018 | $3,122 |
| Net income (loss) attributable to non-controlling interest | 65 | 191 |
| Net income (loss) | 1,083 | 3,313 |
| Non-cash (gain) loss on derivative instruments, net | (60) | (41) |
| Interest expense, net | 70 | 166 |
| Depreciation, depletion, amortization and accretion | 1,286 | 3,649 |
| Depreciation and interest expense related to equity method investments | 22 | 67 |
| (Gain) loss on extinguishment of debt | 32 | (23) |
| Non-cash equity-based compensation expense | 31 | 85 |
| Capitalized equity-based compensation expense | (9) | (24) |
| Merger and transaction expenses | 17 | 94 |
| Other non-cash transactions | (121) | (153) |
| Provision for (benefit from) income taxes | 287 | 894 |
| Consolidated Adjusted EBITDA | 2,638 | 8,027 |
| Less: Adjustment for non-controlling interest | 230 | 507 |
| Adjusted EBITDA attributable to Diamondback Energy, Inc. | $2,408 | $7,520 |
ADJUSTED NET INCOME
Adjusted net income is a non-GAAP financial measure equal to net income (loss) attributable to Diamondback Energy, Inc. plus net income (loss) attributable to non-controlling interest ("net income (loss)") adjusted for non-cash (gain) loss on derivative instruments, net, (gain) loss on extinguishment of debt, merger and transaction expenses, other non-cash transactions and related income tax adjustments. The Company’s computation of adjusted net income may not be comparable to other similarly titled measures of other companies or to such measure in our credit facility or any of our other contracts. Management believes adjusted net income helps investors in the oil and natural gas industry to measure and compare the Company's performance to other oil and natural gas companies by excluding from the calculation items that can vary significantly from company to company depending upon accounting methods, the book value of assets and other non-operational factors. Further, in order to allow investors to compare the Company's performance across periods, the Company excludes the effects of significant transactions that may affect earnings but are unpredictable in nature, timing and amount, although they may recur in different reporting periods.
The following table presents a reconciliation of the GAAP financial measure of net income (loss) attributable to Diamondback Energy, Inc. to the non-GAAP measure of adjusted net income:
| Three Months Ended September 30, 2025 |
|---|
| Amounts | Amounts Per Diluted Share |
|---|
| Diamondback Energy, Inc. |
| Adjusted Net Income |
| (unaudited, $ in millions except per share data, shares in thousands) |
| Net income (loss) attributable to Diamondback Energy, Inc. | $1,018 | $3.51 |
| Net income (loss) attributable to non-controlling interest | 65 | 0.23 |
| Net income (loss) | 1,083 | 3.74 |
| Non-cash (gain) loss on derivative instruments, net | (60) | (0.21) |
| (Gain) loss on extinguishment of debt | 32 | 0.11 |
| Merger and transaction expenses | 17 | 0.06 |
| Other non-cash transactions | (121) | (0.42) |
| Adjusted net income excluding above items | 951 | 3.28 |
| Income tax adjustment for above items | 28 | 0.10 |
| Adjusted net income | 979 | 3.38 |
| Less: Adjusted net income attributable to non-controlling interest | 84 | 0.30 |
| Adjusted net income attributable to Diamondback Energy, Inc. | $895 | $3.08 |
| Weighted average common shares outstanding: | | |
| Basic | 288,826 |
| Diluted | 288,826 |
(1) The Company’s earnings (loss) per diluted share amount has been computed using the two-class method in accordance with GAAP. The two-class method is an earnings allocation which reflects the respective ownership among holders of common stock and participating securities. Diluted earnings per share using the two-class method is calculated as (i) net income attributable to Diamondback Energy, Inc, (ii) less the reallocation of $4 million in earnings attributable to participating securities, (iii) divided by diluted weighted average common shares outstanding for the respective periods.
OPERATING CASH FLOW BEFORE WORKING CAPITAL CHANGES, FREE CASH FLOW AND ADJUSTED FREE CASH FLOW
Operating cash flow before working capital changes, which is a non-GAAP financial measure, represents net cash provided by operating activities as determined under GAAP without regard to changes in working capital. The Company believes operating cash flow before working capital changes is a useful measure of an oil and natural gas company’s ability to generate cash used to fund exploration, development and acquisition activities and service debt or pay dividends. The Company also uses this measure because changes in working capital relate to the timing of cash receipts and disbursements that the Company may not control and may not relate to the period in which the operating activities occurred. This allows the Company to compare its operating performance with that of other companies without regard to financing methods and capital structure.
The Company defines Free Cash Flow, which is a non-GAAP financial measure, as cash flow from operating activities before changes in working capital in excess of cash capital expenditures. The Company defines Adjusted Free Cash Flow, which is a non-GAAP financial measure, as Free Cash Flow before merger and transaction expenses, costs of early termination of derivatives and settlements of any treasury locks. The Company believes that Free Cash Flow and Adjusted Free Cash Flow are useful to investors as they provide a measure to compare both cash flow from operating activities and additions to oil and natural gas properties across periods on a consistent basis, adjusted, as applicable, for non-recurring impacts from divestitures, merger and transaction expenses, the early termination of derivative contracts and settlements of treasury locks. These measures should not be considered as an alternative to, or more meaningful than, net cash provided by operating activities as an indicator of liquidity. The Company's computation of Free Cash Flow may not be comparable to other similarly titled measures of other companies. Currently, the Board has approved a return of capital commitment of at least 50% of Adjusted Free Cash Flow to the Company's stockholders through repurchases under the share repurchase program, base dividends and variable dividends.
The following tables present a reconciliation of the GAAP financial measure of net cash provided by operating activities to the non-GAAP measure of operating cash flow before working capital changes and to the non-GAAP measures of Free Cash Flow and Adjusted Free Cash Flow:
| Three Months Ended September 30, 2025 | Nine Months Ended September 30, 2025 |
|---|
| Diamondback Energy, Inc. | |
| Operating Cash Flow Before Working Capital Changes, Free Cash Flow and Adjusted Free Cash Flow | |
| (unaudited, in millions) | |
| Net cash provided by operating activities | $2,383 | $6,415 |
| Less: Changes in cash due to changes in operating assets and liabilities: | | |
| Accounts receivable | (22) | 138 |
| Income tax receivable | - | 3 |
| Prepaid expenses and other current assets | (49) | (65) |
| Accounts payable and accrued liabilities | 28 | (355) |
| Income taxes payable | (206) | (515) |
| Revenues and royalties payable | 58 | 28 |
| Other | 40 | 54 |
| Total working capital changes | (151) | (712) |
| Operating cash flow before working capital changes | 2,534 | 7,127 |
| Additions to oil and natural gas properties | (774) | (2,580) |
| Total Cash CAPEX | (774) | (2,580) |
| Free Cash Flow | 1,760 | 4,547 |
| Merger and transaction expenses | 17 | 94 |
| Early termination of derivatives | 15 | 67 |
| Treasury locks | - | 1 |
| Adjusted Free Cash Flow | $1,792 | $4,709 |
(1) Includes $15 million and $25 million of Viper's transaction expenses related to the Sitio Acquisition and the Drop Down for the three and nine months ended September 30, 2025, respectively.
NET DEBT
The Company defines the non-GAAP measure of net debt as total debt (excluding debt issuance costs, discounts, premiums and unamortized basis adjustments) less cash and cash equivalents and restricted cash that has been irrevocably deposited for the redemption of principal amounts of outstanding senior notes. Net debt should not be considered an alternative to, or more meaningful than, total debt, the most directly comparable GAAP measure. Management uses net debt to determine the Company's outstanding debt obligations that would not be readily satisfied by its cash and cash equivalents on hand. The Company believes this metric is useful to analysts and investors in determining the Company's leverage position because the Company has the ability to, and may decide to, use a portion of its cash and cash equivalents to reduce debt.
| September 30, 2025 | Net Q3 Principal Borrowings/(Repayments) | June 30, 2025 | March 31, 2025 | December 31, 2024 | September 30, 2024 |
|---|
| (in millions) |
|---|
| Diamondback Energy, Inc. |
| Net Debt |
| (unaudited, in millions) |
| Diamondback Energy, Inc. | $13,792 | $(420) | $14,212 | $13,269 | $12,069 | $12,284 |
| Viper Energy, Inc. | 2,640 | 1,535 | 1,105 | 830 | 1,091 | 830 |
| Total debt | 16,432 | $1,115 | 15,317 | 14,099 | 13,160 | 13,114 |
| Cash and cash equivalents | (539) | | (219) | (1,816) | (161) | (370) |
| Net debt | $15,893 | | $15,098 | $12,283 | $12,999 | $12,744 |
(1) Excludes debt issuance costs, discounts, premiums and unamortized basis adjustments.
(2)Cash and cash equivalents at September 30, 2025 includes $380 million of restricted cash which Viper irrevocably deposited with Computershare Trust Company, National Association in July 2025 for the redemption of the principal amount of Viper's 5.375% Senior Notes due 2027 on November 1, 2025.
DERIVATIVES
As of October 31, 2025, the Company had the following outstanding consolidated derivative contracts, including derivative contracts at Viper. The Company’s derivative contracts are based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on New York Mercantile Exchange West Texas Intermediate pricing and Crude Oil Brent pricing and with natural gas derivative settlements based on the New York Mercantile Exchange Henry Hub pricing. When aggregating multiple contracts, the weighted average contract price is disclosed.
| Crude Oil (Bbls/day, $/Bbl) |
|---|
| Q4 2025 | | Q1 2026 | | Q2 2026 | | Q3 2026 | | Q4 2026 |
|---|
| Long Puts - Crude Brent Oil | 46,000 | | 36,000 | | 22,000 | | 5,000 | | - |
| Long Put Price ($/Bbl) | $53.91 | | $53.13 | | $52.50 | | $52.50 | | - |
| Deferred Premium ($/Bbl) | $-1.64 | | $-1.73 | | $-1.73 | | $-1.63 | | - |
| Long Puts - WTI (Magellan East Houston) | 100,000 | | 95,000 | | 60,000 | | 15,000 | | - |
| Long Put Price ($/Bbl) | $53.00 | | $51.13 | | $50.00 | | $50.00 | | - |
| Deferred Premium ($/Bbl) | $-1.68 | | $-1.66 | | $-1.66 | | $-1.74 | | - |
| Long Puts - WTI (Cushing) | 176,000 | | 175,000 | | 80,000 | | 10,000 | | - |
| Long Put Price ($/Bbl) | $53.79 | | $51.83 | | $49.53 | | $50.00 | | - |
| Deferred Premium ($/Bbl) | $-1.64 | | $-1.63 | | $-1.66 | | $-1.83 | | - |
| Basis Swaps - WTI (Midland) | 76,000 | | 30,000 | | 30,000 | | 25,000 | | 25,000 |
| $1.05 | | $0.96 | | $0.96 | | $0.95 | | $0.95 | |
| Roll Swaps - WTI | 65,000 | | - | | - | | - | | - |
| $1.07 | | - | | - | | - | | - | |
| Natural Gas (Mmbtu/day, $/Mmbtu) |
|---|
| Q4 2025 | | FY 2026 | | FY 2027 |
|---|
| Costless Collars - Henry Hub | 690,000 | | 840,000 | | 580,000 |
| Floor Price ($/Mmbtu) | $2.49 | | $2.87 | | $2.91 |
| Ceiling Price ($/Mmbtu) | $5.28 | | $6.35 | | $6.37 |
| Natural Gas Basis Swaps - Waha Hub | 610,000 | | 650,000 | | 300,000 |
| $-0.98 | | $-1.69 | | $-1.35 | |
| Natural Gas Basis Swaps - Houston Ship Channel | 20,000 | | 100,000 | | 120,000 |
| $-0.49 | | $-0.35 | | $-0.25 | |
Contacts
Adam Lawlis
+1 432.221.7467 alawlis@diamondbackenergy.com
Open the filing on EDGARLETTER TO STOCKHOLDERS ISSUED BY DIAMONDBACK ENERGY, INC.
Diamondback Stockholders,
This letter is meant to be a supplement to our earnings release and is being furnished to the Securities and Exchange Commission (SEC) and released to our stockholders simultaneously with our earnings release. Please see the information regarding forward-looking statements and non-GAAP financial information included at the end of this letter.
Macro Update
A couple of quarters ago, we began to tie the macro environment and our corresponding activity levels to the colors of a stoplight, where “green” means we accelerate activity for organic growth, “yellow” means we preserve optionality by holding oil volumes roughly flat and growing per share metrics through a reduced share count and “red” means we defend value by reducing activity and preserving inventory while prioritizing our base dividend and reducing our share count until commodity pricing improves. In all cases, these decisions are made to maximize long-term stockholder value and grow per share metrics.
We remain in the “yellow” zone today, while retaining all operational flexibility for green or red. Global oil demand growth is healthy and the forward demand outlook looks constructive. However, current and future oil supply growth has become a hotly contested debate. The forecasted Q4 2025 and first half 2026 oil oversupply ranges from less than 500k barrels per day per OPEC forecasts to almost 4 million barrels per day at the IEA. As they say in Texas, “you could drive a truck between those two numbers”. Our best guess on the amount of oversupply lies somewhere in between, with our inherent cognitive bias leaning to support OPEC’s forecast. We also recognize we are unlikely to see positive price signals until this debate is resolved.
Against this backdrop, we firmly believe there is no need for incremental oil barrels until there is a proper price signal. Until that time, we will put our head down and continue to work to lower our industry-leading oil price breakeven, reinvestment rate and cost structure so we can maximize Free Cash Flow to pay our dividend, buy back shares and pay down debt.
Sources:
OPEC Monthly Oil Market Report - October 2025
IEA (2025), As oil market surplus keeps rising, something’s got to give, IEA, Paris https://www.iea.org/commentaries/as-oil-market-surplus-keeps-rising-something-s-got-to-give, Licence: CC BY 4.0
Sitio Acquisition
On August 19, 2025, Viper Energy, our publicly traded mineral and royalty subsidiary, closed its acquisition of Sitio Royalties. The combined company now ranks among the largest minerals and royalty companies in North America, with greater scale across the core of the Permian Basin. This enhanced footprint increases exposure to high quality development activity without adding capital requirements and supports a more resilient stream of zero capital Free Cash Flow.
With its size and scale, Viper is positioned to pursue disciplined transactions in what continues to be a highly fragmented minerals market, apply superior land and data capabilities to source and evaluate opportunities and integrate assets efficiently. Viper now has access to well-level data for ~50% of all horizontal wells in the Permian, a resource that can be maximized with the continued advancement of artificial intelligence and data analytics.
2025 Guidance Update
Over the past two quarters, we reduced 2025 capital expenditures by $500 million (~13%) versus our original 2025 guidance. This was done through a deliberate moderation of activity, coupled with material efficiency gains and synergy capture following the integration of recent acquisitions. Additionally, we benefitted from structural improvements in our cost base, including lower service pricing and an ever-optimizing supply chain given our size and scale. We expect capex to tick up moderately in the fourth quarter to $875 - $975 million (up from $774 million in the third quarter) as our activity reductions from earlier in the year ran through third quarter numbers and we are back to a capital run-rate where oil production is expected to be held flat.
On the volume side, we are revising our annual oil production guidance up to a range of 495 - 498 MBO/d, an increase of 8 MBO/d at the midpoint. In addition, we are raising our annual BOE guidance by approximately 2%, now expected to fall within a range of 910 - 920 MBOE/d. These upward revisions primarily reflect the successful closing of the Sitio acquisition, coupled with continued improvements in gas capture efficiency that we highlighted last quarter.
Third Quarter Operational Performance
Oil production for the third quarter averaged 504 MBO/d (943 MBOE/d), at the top of our 494 - 504 MBO/d (908 - 938 MBOE/d) revised guidance range that we published after closing the Sitio acquisition.
Oil markets are cyclical and the price we receive for the product we produce is beyond our control. What is firmly within our control is the structural integrity of our cost base, adherence to capital discipline and flawless operational execution. Over the long term, in a commodity-based business, the lowest-cost operator wins because returns compound when cost structures stay resilient through the cycle.
Our team continues to deliver on this mandate through rigorous operating practices and optimized development strategies. A key highlight is that our well costs per lateral foot have declined to 2020 COVID-era levels, driven by extended lateral lengths and an uncompromising focus on efficiency and cost control. As a result of activity cadence and well cost reductions, capital expenditures for the quarter totaled $774 million, in the lower half of our $750 - $850 million guidance range.
One of the most notable recent developments has been the pronounced step change in the consistency of improved operational efficiency at scale, which has fundamentally shifted our internal benchmarks. Metrics that previously represented “leading-edge” or “record-setting” performance have now drifted towards the median across our execution machine.
During the most recent quarter, the average number of days from spud to total depth ("TD") for all wells drilled declined to 8.19 days, a new record for the Company. The average days from spud to rig release similarly improved to 10.09 days. Notably, 11% of wells reached TD in under five days, a threshold previously considered exceptional. This includes the fastest 10,000-foot lateral in Company history, drilled to TD in just 3.9 days, as well as two other wells that ranked among the top ten fastest in Company history.
Our completions team continues to deliver exceptional efficiency at scale. While simulfrac is now table stakes for our completion program, the team recently took things a step further with a new concept called “continuous pumping”. On these custom-designed fleets, we are now consistently completing over one mile of lateral footage per day (up from 4,000 lateral feet per day last quarter). Due to this success, we expect to convert all our fleets to continuous pumping within the next couple quarters.
Cash operating costs fell again this quarter to $10.05/BOE. As we discussed in our last letter, LOE ticked up slightly this quarter as we saw an expected increase in spend on well-work and artificial lift. Our production operations teams are diligently working to drive process automation using machine learning and artificial intelligence to optimize lift type and cost while delivering structural gains through reducing downtime and improving performance of wells that are closer to the tail of their production curves, among many other field-based initiatives.
Third Quarter Financial Performance and Return of Capital
We generated $2.4 billion in net cash from operating activities in the third quarter, which translated into $1.8 billion of Free Cash Flow and Adjusted Free Cash Flow. Third quarter operating cash flow and Free Cash Flow benefitted from a tailwind related to the ‘One Big Beautiful Bill’, which lowered our estimated year-to-date cash tax rate and resulted in a significant cash tax true-up during the quarter.
Year-to-date through September, Diamondback has now generated ~2% more operating cash flow per share and ~15% more Adjusted Free Cash Flow per share compared to the same period in 2024 despite our average realized oil price declining ~13% to ~$66 per barrel from ~$76 per barrel over the same period. This is a testament to cost control, capital efficiency and tangible synergy capture since our merger with Endeavor closed just over one year ago.
Our commitment to stockholder returns remains steadfast, as seen through the return of approximately $892 million to stockholders in the third quarter through our base dividend and stock repurchases, representing ~50% of Adjusted Free Cash Flow.
In the third quarter, we accelerated our share repurchase activity, retiring approximately 4.3 million shares for ~$603 million at an average price of $140.70 per share. This is the largest quarterly buyback in our Company’s history, both in terms of shares repurchased and capital deployed. To provide context, these repurchases accounted for ~3.5% of average daily trading volume during the quarter and reduced our shares outstanding by approximately 1.5%. Year-to-date through September, we have repurchased 10.9 million shares for $1.6 billion. This reflects our commitment to prioritize stockholder returns over capex regardless of continued efficiency gains given current macro conditions. We expect to conclude 2025 with more shares repurchased than both 2023 and 2024 combined, underscoring our conviction that the Company is undervalued today relative to our view of long-term intrinsic value.
Non-Core Asset Sales
We recently completed both large divestitures previously announced in September. On October 1, 2025, we closed the sale of Environmental Disposal Systems, LLC to Deep Blue Midland Basin LLC ("Deep Blue"), retaining a 30% equity interest in Deep Blue and receiving $694 million in upfront cash proceeds. Subsequently, on October 31st, we completed the divestiture of our 27.5% equity interest in EPIC Crude Holdings, LP, generating $504 million of upfront cash proceeds.
At the time of the Double Eagle acquisition announcement in February, we committed to executing at least $1.5 billion in non-core asset sales. While we told the market we expected to achieve this goal over about 18 months, our team delivered ahead of expectations. Through these two major transactions, together with proceeds from the sale of the BANGL pipeline and Delaware Basin non-operated properties, we have successfully exceeded (inclusive of potential future earnouts) our $1.5 billion target in just over six months.
Balance Sheet
Consolidated gross debt increased by $1.1 billion and consolidated net debt increased by roughly $795 million sequentially in the third quarter. The increase was primarily driven by the issuance of new Viper notes to fund the redemption of Sitio's debt at acquisition close, partially offset by Free Cash Flow generation and non-core asset sale proceeds at Diamondback. We ended the quarter with consolidated gross debt of approximately $16.4 billion and $15.9 billion of consolidated net debt.
We expect net debt to decline significantly in the fourth quarter through the combination of continued Free Cash Flow generation and significant cash inflow from non-core asset sale proceeds. We recently reduced our 2025 term loan balance by $500 million to $1.0 billion and expect to continue to reduce this balance over the coming quarters. In addition, we repurchased $203 million in aggregate principal amount of our longer-dated bonds at a weighted average price of 82.3% of par (approximately $167 million cash outflow) during the first month of the fourth quarter.
Closing
As seen in this quarter’s results, our relentless focus on capital allocation, execution and cost discipline positions us well for whatever color the proverbial “stoplight” may turn.
“Never underestimate the American engineer” is a phrase I have personally come to appreciate in recent months. These professionals are the foundation of the shale revolution and will continue to evolve, invent and discover new things regardless of current commodity prices and macro sentiment.
Thank you for your interest in Diamondback Energy.
Sincerely,
Kaes Van't Hof
Chief Executive Officer and Director
Forward-looking statements notice
This letter contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act of 1934, as amended, which involve risks, uncertainties, and assumptions. All statements, other than statements of historical fact, including statements regarding future performance; business strategy; future operations (including drilling plans and capital plans); estimates and projections of revenues, losses, costs, expenses, returns, cash flow, and financial position; reserve estimates and its ability to replace or increase reserves; anticipated benefits or other effects of strategic transactions (including the Sitio acquisition, the Endeavor merger, the Double Eagle acquisition, Viper drop-down and other acquisitions or divestitures); and plans and objectives of management (including plans for future cash flow from operations and for executing environmental strategies) are forward-looking statements. When used in this letter, the words “aim,” “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,” “intend,” “may,” “model,” “outlook,” “plan,” “positioned,” “potential,” “predict,” “project,” “seek,” “should,” “target,” “will,” “would,” and similar expressions (including the negative of such terms) are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Although Diamondback believes that the expectations and assumptions reflected in its forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond Diamondback’s control. Accordingly, forward-looking statements are not guarantees of future performance and actual outcomes could differ materially from what Diamondback has expressed in its forward-looking statements.
Factors that could cause the outcomes to differ materially include (but are not limited to) the following: changes in supply and demand levels for oil, natural gas and natural gas liquids and the resulting impact on the price for those commodities; the impact of public health crises, including epidemic or pandemic diseases and any related company or government policies or actions; actions taken by the members of OPEC and Russia affecting the production and pricing of oil, as well as other domestic and global political, economic, or diplomatic developments; changes in general economic, business or industry conditions, including changes in foreign currency exchange rates, interest rates and inflation rates, instability in the financial sector; regional supply and demand factors, including delays, curtailment delays or interruptions of production, or governmental orders, rules or regulations that impose production limits; federal and state legislative and regulatory initiatives relating to hydraulic fracturing, including the effect of existing and future laws and governmental regulations; physical and transition risks relating to climate change; restrictions on the use of water, including limits on the use of produced water and a moratorium on new produced water well permits recently imposed by the Texas Railroad Commission in an effort to control induced seismicity in the Permian Basin; significant declines in prices for oil, natural gas, or natural gas liquids, which could require recognition of significant impairment charges; changes in U.S. energy, environmental, monetary and trade policies, including with respect to tariffs or other trade barriers and any resulting trade tensions; conditions in the capital, financial and credit markets, including the availability and pricing of capital for drilling and development operations and our environmental and social responsibility projects; challenges with employee retention and an increasingly competitive labor market; changes in availability or cost of rigs, equipment, raw materials, supplies and oilfield services; changes in safety, health, environmental, tax and other regulations or requirements (including those addressing air emissions, water management, or the impact of global climate change); security threats, including cybersecurity threats and disruptions to our business and operations from breaches of our information technology systems, or from breaches of information technology systems of third parties with whom we transact business; lack of, or disruption in, access to adequate and reliable transportation, processing, storage and other facilities for our oil, natural gas and natural gas liquids; failures or delays in achieving expected reserve or production levels from existing and future oil and natural gas developments, including due to operating hazards, drilling risks, or the inherent uncertainties in predicting reserve and reservoir performance; difficulty in obtaining necessary approvals and permits; severe weather conditions and natural disasters; acts of war or terrorist acts and the governmental or military response thereto; changes in the financial strength of counterparties to our credit agreement and hedging contracts; changes in our credit rating; risks related to the Endeavor merger, Double Eagle acquisition, 2025 drop down and Sitio acquisition; and other risks described in Part I, Item 1A of Diamondback’s Annual Report on Form 10-K, filed with the SEC on February 26, 2025, and those risks disclosed in its subsequent filings on Forms 10-Q and 8-K, which can be obtained free of charge on the SEC’s website at http://www.sec.gov and Diamondback’s website at www.diamondbackenergy.com/investors.
In light of these factors, the events anticipated by Diamondback’s forward-looking statements may not occur at the time anticipated or at all. Moreover, Diamondback operates in a very competitive and rapidly changing environment and new risks emerge from time to time. Diamondback cannot predict all risks, nor can it assess the impact of all factors on its business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those anticipated by any forward-looking statements it may make. Accordingly, you should not place undue reliance on any forward-looking statements. All forward-looking statements speak only as of the date of this letter or, if earlier, as of the date they were made. Diamondback does not intend to, and disclaims any obligation to, update or revise any forward-looking statements unless required by applicable law.
Non-GAAP Financial Measures
This letter includes financial information not prepared in conformity with generally accepted accounting principles (GAAP), such as Free Cash Flow, Adjusted Free Cash Flow and net debt. The non-GAAP information should be considered by the reader in addition to, but not instead of, financial information prepared in accordance with GAAP. A reconciliation of the differences between these non-GAAP financial measures and the most directly comparable GAAP financial measures can be found in Diamondback's quarterly results, which are posted on Diamondback's website at www.diamondbackenergy.com/investors/ and included as Exhibit 99.1 to the Current Report on Form 8-K filed by Diamondback with the SEC that also includes this letter as Exhibit 99.2. Furthermore, this letter includes or references certain forward-looking, non-GAAP financial measures. Because Diamondback provides these measures on a forward-looking basis, it cannot reliably or reasonably predict certain of the necessary components of the most directly comparable forward-looking GAAP financial measures, such as future impairments and future changes in working capital. Accordingly, Diamondback is unable to present a quantitative reconciliation of such forward-looking, non-GAAP financial measures to the respective most directly comparable forward-looking GAAP financial measures. Diamondback believes that these forward-looking, non-GAAP measures may be a useful tool for the investment community in comparing Diamondback's forecasted financial performance to the forecasted financial performance of other companies in the industry.
Contacts
Adam Lawlis
+1 432.221.7467 alawlis@diamondbackenergy.com
Forward-Looking Statements: