UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
___________
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of the
Securities Exchange Act of 1934
Date of report (Date of earliest event reported): November 6, 2023
___________
(Exact Name of Registrant as Specified in Charter)
(State or other jurisdiction of incorporation) | (Commission File Number) | (I.R.S. Employer Identification Number) | |||||||||||||||
| (Address of principal executive offices) | (Zip code) | ||||||||||||||||
(432 ) 221-7400
(Registrant's telephone number, including area code)
Not Applicable
(Former name or former address, if changed since last report)
Check the appropriate box below if the Form 8-K is intended to simultaneously satisfy the filing obligation of the Registrant under any of the following provisions:
Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered | ||||||
| (NASDAQ Global Select Market) | ||||||||
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging growth company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Item 2.02. Results of Operations and Financial Condition.
On November 6, 2023, Diamondback Energy, Inc. (the “Company”) issued a press release announcing financial and operating results for the third quarter ended September 30, 2023 and announcing the third quarter 2023 base and variable cash dividends (the “earnings release”). A copy of the earnings release is furnished to the Securities and Exchange Commission (the “SEC”) as Exhibit 99.1 to this Current Report on Form 8-K. The Company also issued a letter to its stockholders as a supplement to the earnings release, which is furnished to the SEC as Exhibit 99.2 to this Current Report on Form 8-K.
Item 9.01. Financial Statements and Exhibits.
(d) Exhibits
| Exhibit Number | Description | |||||||
| 99.1 | ||||||||
| 99.2 | ||||||||
| 104 | Cover Page Interactive Data File (formatted as Inline XBRL). | |||||||
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| DIAMONDBACK ENERGY, INC. | ||||||||||||||
| Date: | November 6, 2023 | |||||||||||||
| By: | /s/ Teresa L. Dick | |||||||||||||
| Name: | Teresa L. Dick | |||||||||||||
| Title: | Executive Vice President, Chief Accounting Officer and Assistant Secretary | |||||||||||||
Exhibit 99.1
DIAMONDBACK ENERGY, INC. ANNOUNCES THIRD QUARTER 2023 FINANCIAL AND OPERATING RESULTS
Midland, TX (November 6, 2023) - Diamondback Energy, Inc. (NASDAQ: FANG) (“Diamondback” or the “Company”) today announced financial and operating results for the third quarter ended September 30, 2023.
THIRD QUARTER 2023 HIGHLIGHTS
•Average production of 266.1 MBO/d (452.8 MBOE/d)
•Net cash provided by operating activities of $1.4 billion; Operating Cash Flow Before Working Capital Changes (as defined and reconciled below) of $1.5 billion
•Cash capital expenditures of $684 million
•Free Cash Flow (as defined and reconciled below) of $820 million; Adjusted Free Cash Flow (as defined and reconciled below) of $884 million
•Declared Q3 2023 base cash dividend of $0.84 per share and a variable cash dividend of $2.53 per share, in each case payable on November 24, 2023; implies an 8.3% annualized yield based on November 3, 2023 closing share price of $162.10
•Repurchased 406,700 shares of common stock in Q3 2023 for $56 million (at a weighted average price of $136.59/share); repurchased 217,900 shares of common stock to date in Q4 2023 for $32 million, excluding excise tax (at a weighted average price of $146.97/share)
•Total Q3 2023 return of capital of $663 million; represents ~81% of Q3 2023 Free Cash Flow and 75% of Adjusted Free Cash Flow from stock repurchases and the declared Q3 2023 base-plus-variable dividend
•As previously announced, completed joint venture transaction with Five Point Energy LLC, forming Deep Blue Midland Basin LLC ("Deep Blue"), contributing certain Midland Basin water assets for gross proceeds of $516 million and 30% equity ownership in the new joint venture entity
•In September, completed divestiture of Delaware Basin oil gathering assets for gross proceeds of $75 million
•Since initiating our non-core asset sale program, have closed transactions with $1.7 billion of gross proceeds, exceeding our year-end 2023 target of $1.0 billion
•Ended Q3 2023 with consolidated total debt of $6.4 billion and consolidated net debt (as defined and reconciled below) of $5.6 billion, down from $6.7 billion as of the end of Q2 2023
OPERATIONS UPDATE
The tables below provide a summary of operating activity for the third quarter of 2023.
| Total Activity (Gross Operated): | |||||||||||
| Number of Wells Drilled | Number of Wells Completed | ||||||||||
| Midland Basin | 79 | 73 | |||||||||
| Delaware Basin | 7 | 1 | |||||||||
| Total | 86 | 74 | |||||||||
| Total Activity (Net Operated): | |||||||||||
| Number of Wells Drilled | Number of Wells Completed | ||||||||||
| Midland Basin | 69 | 70 | |||||||||
| Delaware Basin | 6 | 1 | |||||||||
| Total | 75 | 71 | |||||||||
During the third quarter of 2023, Diamondback drilled 79 gross wells in the Midland Basin and seven gross wells in the Delaware Basin. The Company turned 73 operated wells to production in the Midland Basin and one gross well in the Delaware Basin with an average lateral length of 11,864 feet. Operated completions during the third quarter consisted of 25 Lower Spraberry wells, 20 Wolfcamp A wells, 11 Jo Mill wells, eight Wolfcamp B wells, seven Middle Spraberry wells, one Third Bone Spring well, one Upper Spraberry well and one Barnett well.
For the first nine months of 2023, Diamondback drilled 235 gross wells in the Midland Basin and 31 gross wells in the Delaware Basin. The Company turned 213 operated wells to production in the Midland Basin and 38 operated wells to production in the Delaware Basin. The average lateral length for wells completed during the first nine months of 2023 was 11,184 feet, and consisted of 69 Lower Spraberry wells, 64 Wolfcamp A wells, 41 Wolfcamp B wells, 32 Jo Mill wells, 18 Middle Spraberry wells, 15 Third Bone Spring wells, eight Second Bone Spring wells, two Upper Spraberry wells and two Barnett wells.
FINANCIAL UPDATE
Diamondback's third quarter 2023 net income was $915 million, or $5.07 per diluted share. Adjusted net income (as defined and reconciled below) was $990 million, or $5.49 per diluted share.
Third quarter 2023 net cash provided by operating activities was $1.4 billion. Through the first nine months of 2023, Diamondback's net cash provided by operating activities was $4.3 billion.
During the third quarter of 2023, Diamondback spent $611 million on operated and non-operated drilling and completions, $34 million on infrastructure and environmental and $39 million on midstream, for total cash capital expenditures of $684 million for the quarter. During the first nine months of 2023, Diamondback has spent $1.8 billion on operated and non-operated drilling and completions, $122 million on infrastructure and environmental and $104 million on midstream, for total cash capital expenditures of $2.1 billion.
Third quarter 2023 Consolidated Adjusted EBITDA (as defined and reconciled below) was $1.8 billion. Adjusted EBITDA net of non-controlling interest (as defined and reconciled below) was $1.7 billion.
Diamondback's third quarter 2023 Free Cash Flow (as defined and reconciled below) was $820 million. Adjusted Free Cash Flow (as defined and reconciled below) was $884 million. Through September 30, 2023, Diamondback's Free Cash Flow was $2.0 billion, with $2.1 billion of Adjusted Free Cash Flow over the same period.
Third quarter 2023 average unhedged realized prices were $81.57 per barrel of oil, $1.62 per Mcf of natural gas and $21.02 per barrel of natural gas liquids ("NGLs"), resulting in a total equivalent unhedged realized price of $54.37 per BOE.
Diamondback's cash operating costs for the third quarter of 2023 were $10.51 per BOE, including lease operating expenses ("LOE") of $5.42 per BOE, cash general and administrative ("G&A") expenses of $0.51 per BOE, production and ad valorem taxes of $2.83 per BOE and gathering and transportation expenses of $1.75 per BOE.
As of September 30, 2023, Diamondback had $680 million in standalone cash and no borrowings under its revolving credit facility, with approximately $1.6 billion available for future borrowing under the facility and approximately $2.3 billion of total liquidity. As of September 30, 2023, the Company had consolidated total debt of $6.4 billion and consolidated net debt of $5.6 billion, down from consolidated total debt and net debt of $6.7 billion as of June 30, 2023.
DIVIDEND DECLARATIONS
Diamondback announced today that the Company's Board of Directors declared a base cash dividend of $0.84 per common share for the third quarter of 2023 payable on November 24, 2023, to stockholders of record at the close of business on November 16, 2023.
The Company's Board of Directors also declared a variable cash dividend of $2.53 per common share for the third quarter of 2023 payable on November 24, 2023, to stockholders of record at the close of business on November 16, 2023.
Future base and variable dividends remain subject to review and approval at the discretion of the Company's Board of Directors.
COMMON STOCK REPURCHASE PROGRAM
During the third quarter of 2023, Diamondback repurchased 406,700 shares of common stock at an average share price of $136.59 for a total cost of approximately $56 million, excluding excise tax. To date, Diamondback has repurchased 18,403,732 shares of common stock at an average share price of $123.28 for a total cost of approximately $2.3 billion and has approximately $1.7 billion remaining on its current share buyback authorization. Diamondback intends to continue to purchase common stock under the common stock repurchase program opportunistically with cash on hand, free cash flow from operations and proceeds from potential liquidity events such as the sale of assets. This repurchase program has no time limit and may be suspended from time to time, modified, extended or discontinued by the Board at any time. Purchases under the repurchase program may be made from time to time in privately negotiated transactions, or in open market transactions in compliance with Rule 10b-18 under the Securities
Exchange Act of 1934, as amended, and will be subject to market conditions, applicable legal requirements and other factors. Any common stock purchased as part of this program will be retired.
FULL YEAR 2023 GUIDANCE
Below is Diamondback's guidance for the full year 2023, which includes fourth quarter production, cash tax and capital guidance. The Company is raising both total and net oil production for the full year 2023 due to production outperformance year-to-date as well as narrowing unit costs, capital expenditures and activity levels.
| 2023 Guidance | 2023 Guidance | |||||||
| Diamondback Energy, Inc. | Viper Energy Partners LP | |||||||
| Net production - MBOE/d | ~447 (from 435 - 445) | ~39.25 | ||||||
| Oil production - MBO/d | ~263 (from 260 - 262) | ~22.00 | ||||||
Q4 2023 oil production - MBO/d (total - MBOE/d) | 269 - 273 (455 - 460) | 24.25 - 24.75 (43.25 - 44.25) | ||||||
| Unit costs ($/BOE) | ||||||||
| Lease operating expenses, including workovers | $5.10 - $5.40 (from $4.90 - $5.40) | |||||||
| G&A | ||||||||
| Cash G&A | $0.55 - $0.65 (from $0.60 - $0.75) | $0.50 - $0.60 | ||||||
| Non-cash equity-based compensation | $0.30 - $0.40 (from $0.35 - $0.45) | $0.10 - $0.15 | ||||||
| DD&A | $10.50 - $10.75 (from $10.00 - $10.75) | $9.50 - $10.00 | ||||||
| Interest expense (net of interest income) | $1.10 - $1.25 (from $1.20 - $1.30) | $3.00 - $3.25 | ||||||
| Gathering and transportation | $1.65 - $1.80 (from $1.80 - $2.00) | |||||||
| Production and ad valorem taxes (% of revenue) | ~7% (from ~8%) | ~7% | ||||||
| Corporate tax rate (% of pre-tax income) | 23% | 20% - 22% | ||||||
| Cash tax rate (% of pre-tax income) | 15% - 17% (from 10% - 15%) | |||||||
Q4 2023 Cash taxes ($ - million) | $190 - $230 | $13.0 - $17.0 | ||||||
| Capital Budget ($ - million) | ||||||||
| Drilling, completion, capital workovers, and non-operated properties | $2,370 - $2,390 (from $2,330 - $2,365) | |||||||
| Midstream (ex. equity method investments) | $120 - $130 (from $100 - $120) | |||||||
| Infrastructure and environmental | $170 - $180 (from $170 - $190) | |||||||
| 2023 Capital expenditures | $2,660 - $2,700 (from $2,600 - $2,675) | |||||||
Q4 2023 Capital expenditures | $610 - $650 | |||||||
| Gross horizontal wells drilled (net) | 340 - 350 (306 - 315) (from 335 - 350 (302 - 315)) | |||||||
| Gross horizontal wells completed (net) | 325 - 335 (305 - 315) (from 330 - 345 (305 - 320)) | |||||||
| Average lateral length (Ft.) | ~11,000' (from ~10,800') | |||||||
| FY 2023 Midland Basin well costs per lateral foot | $620 - $680 | |||||||
| FY 2023 Delaware Basin well costs per lateral foot | $900 - $1,000 | |||||||
| Midland Basin net lateral feet (%) | ~85% | |||||||
| Delaware Basin net lateral feet (%) | ~15% | |||||||
CONFERENCE CALL
Diamondback will host a conference call and webcast for investors and analysts to discuss its results for the third quarter of 2023 on Tuesday, November 7, 2023 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
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 of strategic transactions (including acquisitions and 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, including any impact of the ongoing war in Ukraine and Israel-Hamas war on the global energy markets and geopolitical stability; instability in the financial sector; concerns over a potential economic slowdown or recession; inflationary pressures; rising interest rates and their impact on the cost of capital; 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 and the risks and other factors disclosed in Diamondback’s filings with the Securities and Exchange Commission, including its Forms 10-K, 10-Q and 8-K, which can be obtained free of charge on the Securities and Exchange Commission’s web site at http://www.sec.gov.
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 made in this news release. All forward-looking statements speak only as of the date of this news 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.
| Diamondback Energy, Inc. | |||||||||||
| Condensed Consolidated Balance Sheets | |||||||||||
| (unaudited, in millions, except share amounts) | |||||||||||
| September 30, | December 31, | ||||||||||
| 2023 | 2022 | ||||||||||
| Assets | |||||||||||
| Current assets: | |||||||||||
| Cash and cash equivalents | $ | 827 | $ | 157 | |||||||
| Restricted cash | 3 | 7 | |||||||||
| Accounts receivable: | |||||||||||
| Joint interest and other, net | 191 | 104 | |||||||||
| Oil and natural gas sales, net | 789 | 618 | |||||||||
| Inventories | 70 | 67 | |||||||||
| Derivative instruments | 1 | 132 | |||||||||
| Income tax receivable | 16 | 284 | |||||||||
| Prepaid expenses and other current assets | 19 | 23 | |||||||||
| Total current assets | 1,916 | 1,392 | |||||||||
| Property and equipment: | |||||||||||
Oil and natural gas properties, full cost method of accounting ($8,239 million and $8,355 million excluded from amortization at September 30, 2023 and December 31, 2022, respectively) | 40,647 | 37,122 | |||||||||
| Other property, equipment and land | 706 | 1,481 | |||||||||
| Accumulated depletion, depreciation, amortization and impairment | (15,988) | (14,844) | |||||||||
| Property and equipment, net | 25,365 | 23,759 | |||||||||
| Funds held in escrow | 50 | 119 | |||||||||
| Equity method investments | 519 | 566 | |||||||||
| Assets held for sale | — | 158 | |||||||||
| Derivative instruments | 1 | 23 | |||||||||
| Deferred income taxes, net | 60 | 64 | |||||||||
| Investment in real estate, net | 85 | 86 | |||||||||
| Other assets | 53 | 42 | |||||||||
| Total assets | $ | 28,049 | $ | 26,209 | |||||||
| Liabilities and Stockholders’ Equity | |||||||||||
| Current liabilities: | |||||||||||
| Accounts payable - trade | $ | 358 | $ | 127 | |||||||
| Accrued capital expenditures | 397 | 480 | |||||||||
| Current maturities of long-term debt | — | 10 | |||||||||
| Other accrued liabilities | 428 | 399 | |||||||||
| Revenues and royalties payable | 782 | 619 | |||||||||
| Derivative instruments | 139 | 47 | |||||||||
| Income taxes payable | 37 | 34 | |||||||||
| Total current liabilities | 2,141 | 1,716 | |||||||||
| Long-term debt | 6,230 | 6,238 | |||||||||
| Derivative instruments | 199 | 148 | |||||||||
| Asset retirement obligations | 240 | 336 | |||||||||
| Deferred income taxes | 2,243 | 2,069 | |||||||||
| Other long-term liabilities | 12 | 12 | |||||||||
| Total liabilities | 11,065 | 10,519 | |||||||||
| Stockholders’ equity: | |||||||||||
Common stock, $0.01 par value; 400,000,000 shares authorized; 178,815,302 and 179,840,797 shares issued and outstanding at September 30, 2023 and December 31, 2022, respectively | 2 | 2 | |||||||||
| Additional paid-in capital | 14,149 | 14,213 | |||||||||
| Retained earnings (accumulated deficit) | 2,136 | 801 | |||||||||
| Accumulated other comprehensive income (loss) | (7) | (7) | |||||||||
| Total Diamondback Energy, Inc. stockholders’ equity | 16,280 | 15,009 | |||||||||
| Non-controlling interest | 704 | 681 | |||||||||
| Total equity | 16,984 | 15,690 | |||||||||
| Total liabilities and equity | $ | 28,049 | $ | 26,209 | |||||||
| Diamondback Energy, Inc. | |||||||||||||||||||||||
| Condensed Consolidated Statements of Operations | |||||||||||||||||||||||
| (unaudited, $ in millions except per share data, shares in thousands) | |||||||||||||||||||||||
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2023 | 2022 | 2023 | 2022 | ||||||||||||||||||||
| Revenues: | |||||||||||||||||||||||
| Oil, natural gas and natural gas liquid sales | $ | 2,265 | $ | 2,417 | $ | 6,063 | $ | 7,558 | |||||||||||||||
| Sales of purchased oil | 59 | — | 59 | — | |||||||||||||||||||
| Other operating income | 16 | 20 | 62 | 55 | |||||||||||||||||||
| Total revenues | 2,340 | 2,437 | 6,184 | 7,613 | |||||||||||||||||||
| Costs and expenses: | |||||||||||||||||||||||
| Lease operating expenses | 226 | 183 | 618 | 491 | |||||||||||||||||||
| Production and ad valorem taxes | 118 | 156 | 421 | 495 | |||||||||||||||||||
| Gathering and transportation | 73 | 71 | 209 | 191 | |||||||||||||||||||
| Depreciation, depletion, amortization and accretion | 442 | 336 | 1,277 | 979 | |||||||||||||||||||
| Purchased oil expense | 59 | — | 59 | — | |||||||||||||||||||
| General and administrative expenses | 34 | 34 | 111 | 109 | |||||||||||||||||||
| Merger and integration expense | 1 | 11 | 11 | 11 | |||||||||||||||||||
| Other operating expenses | 47 | 32 | 113 | 85 | |||||||||||||||||||
| Total costs and expenses | 1,000 | 823 | 2,819 | 2,361 | |||||||||||||||||||
| Income (loss) from operations | 1,340 | 1,614 | 3,365 | 5,252 | |||||||||||||||||||
| Other income (expense): | |||||||||||||||||||||||
| Interest expense, net | (41) | (43) | (138) | (122) | |||||||||||||||||||
| Other income (expense), net | 37 | (5) | 69 | (3) | |||||||||||||||||||
| Gain (loss) on derivative instruments, net | (76) | (24) | (358) | (677) | |||||||||||||||||||
| Gain (loss) on extinguishment of debt | — | (1) | (4) | (59) | |||||||||||||||||||
| Income (loss) from equity investments | 9 | 19 | 39 | 56 | |||||||||||||||||||
| Total other income (expense), net | (71) | (54) | (392) | (805) | |||||||||||||||||||
| Income (loss) before income taxes | 1,269 | 1,560 | 2,973 | 4,447 | |||||||||||||||||||
| Provision for (benefit from) income taxes | 276 | 290 | 648 | 913 | |||||||||||||||||||
| Net income (loss) | 993 | 1,270 | 2,325 | 3,534 | |||||||||||||||||||
| Net income (loss) attributable to non-controlling interest | 78 | 86 | 142 | 155 | |||||||||||||||||||
| Net income (loss) attributable to Diamondback Energy, Inc. | $ | 915 | $ | 1,184 | $ | 2,183 | $ | 3,379 | |||||||||||||||
| Earnings (loss) per common share: | |||||||||||||||||||||||
| Basic | $ | 5.07 | $ | 6.72 | $ | 12.01 | $ | 18.99 | |||||||||||||||
| Diluted | $ | 5.07 | $ | 6.72 | $ | 12.01 | $ | 18.99 | |||||||||||||||
| Weighted average common shares outstanding: | |||||||||||||||||||||||
| Basic | 178,872 | 174,406 | 180,400 | 176,169 | |||||||||||||||||||
| Diluted | 178,872 | 174,408 | 180,400 | 176,171 | |||||||||||||||||||
| Dividends declared per share | $ | 3.37 | $ | 2.26 | $ | 5.04 | $ | 8.36 | |||||||||||||||
| Diamondback Energy, Inc. | |||||||||||||||||||||||
| Condensed Consolidated Statements of Cash Flows | |||||||||||||||||||||||
| (unaudited, in millions) | |||||||||||||||||||||||
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2023 | 2022 | 2023 | 2022 | ||||||||||||||||||||
| Cash flows from operating activities: | |||||||||||||||||||||||
| Net income (loss) | $ | 993 | $ | 1,270 | $ | 2,325 | $ | 3,534 | |||||||||||||||
| Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities: | |||||||||||||||||||||||
| Provision for (benefit from) deferred income taxes | 10 | 102 | 185 | 375 | |||||||||||||||||||
| Depreciation, depletion, amortization and accretion | 442 | 336 | 1,277 | 979 | |||||||||||||||||||
| (Gain) loss on extinguishment of debt | — | 1 | 4 | 59 | |||||||||||||||||||
| (Gain) loss on derivative instruments, net | 76 | 24 | 358 | 677 | |||||||||||||||||||
| Cash received (paid) on settlement of derivative instruments | (24) | (96) | (62) | (816) | |||||||||||||||||||
| (Income) loss from equity investment | (9) | (19) | (39) | (56) | |||||||||||||||||||
| Equity-based compensation expense | 13 | 14 | 40 | 42 | |||||||||||||||||||
| Other | 3 | 21 | (23) | 57 | |||||||||||||||||||
| Changes in operating assets and liabilities: | |||||||||||||||||||||||
| Accounts receivable | (256) | 267 | (218) | (113) | |||||||||||||||||||
| Income tax receivable | 103 | (2) | 267 | (1) | |||||||||||||||||||
| Prepaid expenses and other | (8) | (31) | 5 | (16) | |||||||||||||||||||
| Accounts payable and accrued liabilities | (28) | (8) | 46 | (29) | |||||||||||||||||||
| Income tax payable | 23 | 28 | 4 | 14 | |||||||||||||||||||
| Revenues and royalties payable | 53 | 19 | 139 | 182 | |||||||||||||||||||
| Other | (33) | (1) | (12) | (4) | |||||||||||||||||||
| Net cash provided by (used in) operating activities | 1,358 | 1,925 | 4,296 | 4,884 | |||||||||||||||||||
| Cash flows from investing activities: | |||||||||||||||||||||||
| Drilling, completions and infrastructure additions to oil and natural gas properties | (645) | (464) | (1,948) | (1,327) | |||||||||||||||||||
| Additions to midstream assets | (39) | (27) | (104) | (69) | |||||||||||||||||||
| Property acquisitions | (168) | (254) | (1,193) | (623) | |||||||||||||||||||
| Proceeds from sale of assets | 868 | 33 | 1,400 | 105 | |||||||||||||||||||
| Other | (1) | (8) | (14) | (38) | |||||||||||||||||||
| Net cash provided by (used in) investing activities | 15 | (720) | (1,859) | (1,952) | |||||||||||||||||||
| Cash flows from financing activities: | |||||||||||||||||||||||
| Proceeds from borrowings under credit facilities | 1,015 | 2,521 | 4,466 | 4,100 | |||||||||||||||||||
| Repayments under credit facilities | (1,332) | (2,556) | (4,368) | (4,119) | |||||||||||||||||||
| Proceeds from senior notes | — | — | — | 750 | |||||||||||||||||||
| Repayment of senior notes | — | (45) | (134) | (1,910) | |||||||||||||||||||
| Proceeds from (repayments to) joint venture | — | (24) | — | (41) | |||||||||||||||||||
| Premium on extinguishment of debt | — | — | — | (49) | |||||||||||||||||||
| Repurchased shares under buyback program | (56) | (472) | (709) | (782) | |||||||||||||||||||
| Repurchased units under buyback program | (10) | (51) | (67) | (122) | |||||||||||||||||||
| Dividends paid to stockholders | (149) | (526) | (841) | (1,174) | |||||||||||||||||||
| Distributions to non-controlling interest | (25) | (71) | (84) | (181) | |||||||||||||||||||
| Other | (7) | (6) | (34) | (42) | |||||||||||||||||||
| Net cash provided by (used in) financing activities | (564) | (1,230) | (1,771) | (3,570) | |||||||||||||||||||
| Net increase (decrease) in cash and cash equivalents | 809 | (25) | 666 | (638) | |||||||||||||||||||
| Cash, cash equivalents and restricted cash at beginning of period | 21 | 59 | 164 | 672 | |||||||||||||||||||
| Cash, cash equivalents and restricted cash at end of period | $ | 830 | $ | 34 | $ | 830 | $ | 34 | |||||||||||||||
| Diamondback Energy, Inc. | |||||||||||||||||
| Selected Operating Data | |||||||||||||||||
| (unaudited) | |||||||||||||||||
| Three Months Ended | |||||||||||||||||
| September 30, 2023 | June 30, 2023 | September 30, 2022 | |||||||||||||||
| Production Data: | |||||||||||||||||
| Oil (MBbls) | 24,482 | 23,946 | 20,638 | ||||||||||||||
| Natural gas (MMcf) | 49,423 | 50,809 | 45,799 | ||||||||||||||
| Natural gas liquids (MBbls) | 8,943 | 8,528 | 7,667 | ||||||||||||||
Combined volumes (MBOE)(1) | 41,662 | 40,942 | 35,938 | ||||||||||||||
| Daily oil volumes (BO/d) | 266,109 | 263,143 | 224,326 | ||||||||||||||
| Daily combined volumes (BOE/d) | 452,848 | 449,912 | 390,630 | ||||||||||||||
| Average Prices: | |||||||||||||||||
| Oil ($ per Bbl) | $ | 81.57 | $ | 71.33 | $ | 89.79 | |||||||||||
| Natural gas ($ per Mcf) | $ | 1.62 | $ | 0.94 | $ | 6.46 | |||||||||||
| Natural gas liquids ($ per Bbl) | $ | 21.02 | $ | 16.42 | $ | 34.96 | |||||||||||
| Combined ($ per BOE) | $ | 54.37 | $ | 46.31 | $ | 67.25 | |||||||||||
Oil, hedged ($ per Bbl)(2) | $ | 80.51 | $ | 70.41 | $ | 87.41 | |||||||||||
Natural gas, hedged ($ per Mcf)(2) | $ | 1.62 | $ | 1.08 | $ | 5.50 | |||||||||||
Natural gas liquids, hedged ($ per Bbl)(2) | $ | 21.02 | $ | 16.42 | $ | 34.96 | |||||||||||
Average price, hedged ($ per BOE)(2) | $ | 53.74 | $ | 45.94 | $ | 64.67 | |||||||||||
| Average Costs per BOE: | |||||||||||||||||
| Lease operating expenses | $ | 5.42 | $ | 4.88 | $ | 5.09 | |||||||||||
| Production and ad valorem taxes | 2.83 | 3.61 | 4.34 | ||||||||||||||
| Gathering and transportation expense | 1.75 | 1.66 | 1.98 | ||||||||||||||
| General and administrative - cash component | 0.51 | 0.51 | 0.56 | ||||||||||||||
| Total operating expense - cash | $ | 10.51 | $ | 10.66 | $ | 11.97 | |||||||||||
| General and administrative - non-cash component | $ | 0.31 | $ | 0.39 | $ | 0.39 | |||||||||||
| Depreciation, depletion, amortization and accretion per BOE | $ | 10.61 | $ | 10.55 | $ | 9.35 | |||||||||||
| Interest expense, net | $ | 0.98 | $ | 1.25 | $ | 1.20 | |||||||||||
(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 integration expense, other non-cash transactions and provision for (benefit from) income taxes, if any. 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 more effectively 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 adds the items listed above to 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. 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 or liquidity. 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:
| Diamondback Energy, Inc. | |||||||||||||||||
| Reconciliation of Net Income (Loss) to Adjusted EBITDA | |||||||||||||||||
| (unaudited, in millions) | |||||||||||||||||
| Three Months Ended | |||||||||||||||||
| September 30, 2023 | June 30, 2023 | September 30, 2022 | |||||||||||||||
| Net income (loss) attributable to Diamondback Energy, Inc. | $ | 915 | $ | 556 | $ | 1,184 | |||||||||||
| Net income (loss) attributable to non-controlling interest | 78 | 30 | 86 | ||||||||||||||
| Net income (loss) | 993 | 586 | 1,270 | ||||||||||||||
| Non-cash (gain) loss on derivative instruments, net | 52 | 150 | (72) | ||||||||||||||
| Interest expense, net | 41 | 51 | 43 | ||||||||||||||
| Depreciation, depletion, amortization and accretion | 442 | 432 | 336 | ||||||||||||||
| Depreciation and interest expense related to equity method investments | 18 | 16 | 17 | ||||||||||||||
| (Gain) loss on extinguishment of debt | — | 4 | 1 | ||||||||||||||
| Non-cash equity-based compensation expense | 21 | 22 | 20 | ||||||||||||||
| Capitalized equity-based compensation expense | (8) | (6) | (6) | ||||||||||||||
| Merger and integration expenses | 1 | 2 | 11 | ||||||||||||||
Other non-cash transactions | (12) | (6) | 1 | ||||||||||||||
| Provision for (benefit from) income taxes | 276 | 165 | 290 | ||||||||||||||
| Consolidated Adjusted EBITDA | 1,824 | 1,416 | 1,911 | ||||||||||||||
| Less: Adjustment for non-controlling interest | 78 | 63 | 54 | ||||||||||||||
| Adjusted EBITDA attributable to Diamondback Energy, Inc. | $ | 1,746 | $ | 1,353 | $ | 1,857 | |||||||||||
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 integration expense; other non-cash transactions and related income tax adjustments, if any. 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.
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:
| Diamondback Energy, Inc. | |||||||||||
| Adjusted Net Income | |||||||||||
| (unaudited, $ in millions except per share data, shares in thousands) | |||||||||||
| Three Months Ended September 30, 2023 | |||||||||||
| Amounts | Amounts Per Diluted Share | ||||||||||
Net income (loss) attributable to Diamondback Energy, Inc.(1) | $ | 915 | $ | 5.07 | |||||||
| Net income (loss) attributable to non-controlling interest | 78 | 0.44 | |||||||||
Net income (loss)(1) | 993 | 5.51 | |||||||||
| Non-cash (gain) loss on derivative instruments, net | 52 | 0.29 | |||||||||
| Merger and integration expense | 1 | 0.01 | |||||||||
| Other non-cash transactions | (12) | (0.07) | |||||||||
Adjusted net income excluding above items(1) | 1,034 | 5.74 | |||||||||
| Income tax adjustment for above items | (9) | (0.05) | |||||||||
Adjusted net income(1) | 1,025 | 5.69 | |||||||||
| Less: Adjusted net income attributable to non-controlling interest | 35 | 0.20 | |||||||||
Adjusted net income attributable to Diamondback Energy, Inc.(1) | $ | 990 | $ | 5.49 | |||||||
| Weighted average common shares outstanding: | |||||||||||
| Basic | 178,872 | ||||||||||
| Diluted | 178,872 | ||||||||||
(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 $8 million in earnings attributable to participating securities, divided by (iii) diluted weighted average common shares outstanding.
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 operating assets and liabilities. 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 adjusted operating cash flow relates 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.
Free Cash Flow, which is a non-GAAP financial measure, is cash flow from operating activities before changes in working capital in excess of cash capital expenditures. Adjusted Free Cash Flow, which is a non-GAAP financial measure, is Free Cash Flow adjusted for early termination of commodity derivative contracts and the tax impact of certain divestitures. The Company believes that Free Cash Flow and Adjusted Free Cash Flow are useful to investors as they provide measures to compare both cash flow from operating activities and additions to oil and natural gas properties across periods on a consistent basis as adjusted for non-recurring early settlements of commodity derivative contracts. These measures should not be considered as an alternative to, or more meaningful than, net cash provided by operating activities as an indicator of operating performance. The Company's computation of operating cash flow before working capital changes, Free Cash Flow and Adjusted Free Cash Flow may not be comparable to other similarly titled measures of other companies. The Company uses Free Cash Flow to reduce debt, as well as return capital to stockholders as determined by the Board of Directors.
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 measure of Free Cash Flow:
| Diamondback Energy, Inc. | |||||||||||||||||||||||
| Operating Cash Flow Before Working Capital Changes, Free Cash Flow and Adjusted Free Cash Flow | |||||||||||||||||||||||
| (unaudited, in millions) | |||||||||||||||||||||||
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2023 | 2022 | 2023 | 2022 | ||||||||||||||||||||
| Net cash provided by operating activities | $ | 1,358 | $ | 1,925 | $ | 4,296 | $ | 4,884 | |||||||||||||||
| Less: Changes in cash due to changes in operating assets and liabilities: | |||||||||||||||||||||||
| Accounts receivable | (256) | 267 | (218) | (113) | |||||||||||||||||||
| Income tax receivable | 103 | (2) | 267 | (1) | |||||||||||||||||||
| Prepaid expenses and other | (8) | (31) | 5 | (16) | |||||||||||||||||||
| Accounts payable and accrued liabilities | (28) | (8) | 46 | (29) | |||||||||||||||||||
| Income tax payable | 23 | 28 | 4 | 14 | |||||||||||||||||||
| Revenues and royalties payable | 53 | 19 | 139 | 182 | |||||||||||||||||||
| Other | (33) | (1) | (12) | (4) | |||||||||||||||||||
| Total working capital changes | (146) | 272 | 231 | 33 | |||||||||||||||||||
| Operating cash flow before working capital changes | 1,504 | 1,653 | 4,065 | 4,851 | |||||||||||||||||||
| Drilling, completions and infrastructure additions to oil and natural gas properties | (645) | (464) | (1,948) | (1,327) | |||||||||||||||||||
| Additions to midstream assets | (39) | (27) | (104) | (69) | |||||||||||||||||||
| Total Cash CAPEX | (684) | (491) | (2,052) | (1,396) | |||||||||||||||||||
| Free Cash Flow | 820 | 1,162 | 2,013 | 3,455 | |||||||||||||||||||
Tax impact from divestitures(1) | 64 | — | 64 | — | |||||||||||||||||||
| Early termination of derivatives | — | 3 | — | 138 | |||||||||||||||||||
| Adjusted Free Cash Flow | $ | 884 | $ | 1,165 | $ | 2,077 | $ | 3,593 | |||||||||||||||
(1) Includes the tax impact for the disposal of certain Midland Basin water assets and Delaware Basin oil gathering assets.
NET DEBT
The Company defines the non-GAAP measure of net debt as total debt less cash and cash equivalents. 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.
| Diamondback Energy, Inc. | |||||||||||||||||||||||||||||||||||
| Net Debt | |||||||||||||||||||||||||||||||||||
| (unaudited, in millions) | |||||||||||||||||||||||||||||||||||
| September 30, 2023 | Net Q3 Principal Borrowings/(Repayments) | June 30, 2023 | March 31, 2023 | December 31, 2022 | September 30, 2022 | ||||||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||||||||
Diamondback Energy, Inc.(1) | $ | 5,697 | $ | (343) | $ | 6,040 | $ | 6,426 | $ | 5,837 | $ | 4,340 | |||||||||||||||||||||||
Viper Energy Partners LP(1) | 680 | 26 | 654 | 700 | 582 | 675 | |||||||||||||||||||||||||||||
Rattler Midstream LP(1) | — | — | — | — | — | 500 | |||||||||||||||||||||||||||||
| Total debt | 6,377 | $ | (317) | 6,694 | 7,126 | 6,419 | 5,515 | ||||||||||||||||||||||||||||
| Cash and cash equivalents | (827) | (18) | (46) | (157) | (27) | ||||||||||||||||||||||||||||||
| Net debt | $ | 5,550 | $ | 6,676 | $ | 7,080 | $ | 6,262 | $ | 5,488 | |||||||||||||||||||||||||
(1) Excludes debt issuance costs, discounts, premiums and fair value hedges.
DERIVATIVES
As of November 3, 2023, the Company had the following outstanding consolidated derivative contracts, including derivative contracts at Viper Energy Partners LP. 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, $/Bbl) | |||||||||||||||||||||||||||||||||||
| Q4 2023 | Q1 2024 | Q2 2024 | Q3 2024 | Q4 2024 | FY 2025 | ||||||||||||||||||||||||||||||
| Long Puts - Crude Brent Oil | 110,000 | 112,000 | 86,000 | 46,000 | 18,000 | — | |||||||||||||||||||||||||||||
| Long Put Price ($/Bbl) | $55.00 | $55.00 | $55.00 | $55.00 | $55.00 | — | |||||||||||||||||||||||||||||
| Deferred Premium ($/Bbl) | $-1.59 | $-1.50 | $-1.50 | $-1.48 | $-1.56 | — | |||||||||||||||||||||||||||||
| Long Puts - WTI (Magellan East Houston) | 28,000 | 32,000 | 22,000 | 14,000 | 2,000 | — | |||||||||||||||||||||||||||||
| Long Put Price ($/Bbl) | $55.00 | $55.00 | $55.00 | $55.00 | $55.00 | — | |||||||||||||||||||||||||||||
| Deferred Premium ($/Bbl) | $-1.67 | $-1.60 | $-1.53 | $-1.50 | $-1.60 | — | |||||||||||||||||||||||||||||
| Long Puts - WTI (Cushing) | 16,000 | 14,000 | 12,000 | — | — | — | |||||||||||||||||||||||||||||
| Long Put Price ($/Bbl) | $56.25 | $58.57 | $60.00 | — | — | — | |||||||||||||||||||||||||||||
| Deferred Premium ($/Bbl) | $-1.70 | $-1.54 | $-1.50 | — | — | — | |||||||||||||||||||||||||||||
Costless Collars - WTI (Cushing) | — | 6,000 | 6,000 | — | — | — | |||||||||||||||||||||||||||||
| Long Put Price ($/Bbl) | — | $65.00 | $65.00 | — | — | — | |||||||||||||||||||||||||||||
Ceiling Price ($/Bbl) | — | $95.55 | $95.55 | — | — | — | |||||||||||||||||||||||||||||
| Basis Swaps - WTI (Midland) | 24,000 | 6,000 | 6,000 | 6,000 | 6,000 | — | |||||||||||||||||||||||||||||
| $0.90 | $1.23 | $1.23 | $1.23 | $1.23 | — | ||||||||||||||||||||||||||||||
Roll Swaps - WTI | — | 30,000 | 30,000 | 30,000 | 30,000 | — | |||||||||||||||||||||||||||||
| — | $0.81 | $0.81 | $0.81 | $0.81 | — | ||||||||||||||||||||||||||||||
| Natural Gas (Mmbtu/day, $/Mmbtu) | |||||||||||||||||||||||||||||||||||
| Q4 2023 | Q1 2024 | Q2 2024 | Q3 2024 | Q4 2024 | FY 2025 | ||||||||||||||||||||||||||||||
| Costless Collars - Henry Hub | 310,000 | 290,000 | 290,000 | 290,000 | 290,000 | — | |||||||||||||||||||||||||||||
| Long Put Price ($/Mmbtu) | $3.18 | $2.83 | $2.83 | $2.83 | $2.83 | — | |||||||||||||||||||||||||||||
| Ceiling Price ($/Mmbtu) | $9.22 | $7.52 | $7.52 | $7.52 | $7.52 | — | |||||||||||||||||||||||||||||
| Natural Gas Basis Swaps - Waha Hub | 330,000 | 380,000 | 380,000 | 380,000 | 380,000 | 190,000 | |||||||||||||||||||||||||||||
| $-1.24 | $-1.18 | $-1.18 | $-1.18 | $-1.18 | $-0.70 | ||||||||||||||||||||||||||||||
Investor Contact:
Adam Lawlis
+1 432.221.7467
alawlis@diamondbackenergy.com
Exhibit 99.2
LETTER TO STOCKHOLDERS ISSUED BY DIAMONDBACK ENERGY, INC.
Midland, TX (November 6, 2023)
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.
The third quarter of 2023 can be summarized as a significant quarter over quarter increase to stockholder returns and reduced capital and operating expenses. Total debt and net debt also decreased by over $300 million and $1 billion, respectively, in the quarter due to the closing of multiple non-core asset sales. In summary, Diamondback continues to execute on our business plan with our best-in-class cost structure and strong balance sheet.
Production:
Third quarter oil and total production, at 266.1 MBO/d and 452.8 MBOE/d respectively, were both above the high end of our third quarter guidance ranges. As a result of this outperformance, combined with the addition of volumes from Viper’s mineral acquisition from GRP that closed last week, we are increasing our full year oil and total production estimates above their prior ranges. The midpoint of annual daily oil production moves to approximately 263 MBO/d from 261 MBO/d, while the midpoint of annual total daily production moves to approximately 447 MBOE/d from 440 MBOE/d.
Production is again expected to grow in the fourth quarter, with estimated fourth quarter oil production projected to be 269 - 273 MBO/d (455 - 460 MBOE/d). We continue to expect to grow oil production organically at a low single digit annual pace next year with a similar level of activity to this year. This is primarily a result of the quality of the acreage we are developing in the Midland Basin with long laterals, multi-well pads and a high mineral interest across the portfolio.
Oil realizations increased quarter over quarter to 99% of West Texas Intermediate ("WTI") pricing for the quarter. We still expect to realize at least 95% of WTI when WTI is at least $65 per barrel, with most quarters above that number. Gas and NGL realizations increased quarter over quarter as each commodity rallied in the third quarter.
We continue to protect our downside exposure through a hedge program where we buy deferred premium puts up to 12 months in advance for oil, with a goal of being at least 60% hedged heading into a respective quarter. For gas, we hedge with wide two-way collars and a well-protected basis exposure. To us, this hedging philosophy is an insurance policy against the extreme downside where we protect our dividend, still generate FCF and manage our leverage ratio while leaving upside exposure to higher commodity prices for our investors.
Capital Expenditures:
Cash capex for the third quarter was $684 million, in the upper half of our quarterly guidance range. We expect cash capex to decline by 5% - 10% in the fourth quarter to $610 - $650 million as we continue to see the benefits of lower well costs, lower drilling activity and a slightly slower completion cadence. We think the midpoint of fourth quarter capex should be a reasonable representative baseline for our 2024 plan assuming current commodity prices. This implies we can grow production organically with lower capex in 2024, thereby generating more FCF and FCF per share assuming the same commodity prices as this year.
This fourth quarter guidance raises our full year 2023 cash capex guidance range to $2.66 - $2.70 billion, or the high end of our initial 2023 guidance range. Through the third quarter, we have drilled approximately 78% of our estimated total lateral footage and completed approximately 77% of our estimated total lateral footage for the year. We are increasing our estimated wells drilled this year to 340 - 350 and reducing our estimated wells turned to production to 325 - 335, as we have outperformed original volume expectations. Our drilled but uncompleted well (“DUC”) count has increased by almost 50 wells this year to 150 wells today versus 100 wells at the beginning of 2023, which will increase our operational flexibility heading into 2024.
Our drilling team continues to push the limits of efficiency. During the third quarter, they drilled two Midland Basin 7,500 foot lateral wells from spud to total depth in under four days each, which is a basin record to our knowledge. On the completion side, we completed over 3,100 lateral feet per day per crew and used ~90% recycled produced water for our Midland Basin program. Pumping hours almost reached 19 hours per day per crew, all at or near efficiency records for Diamondback.
Operating Costs:
Total cash operating costs decreased by $0.15 per BOE quarter over quarter as increases to lease operating (“LOE”) and gathering and transportation expenses were more than offset by decreases to production and ad valorem taxes. General and administrative expenses were essentially flat quarter over quarter. As a result, we have decreased our annual cash operating cost guidance by a combined $0.15 per BOE as well as reduced our expected severance and ad valorem tax rate to 7% of revenue (from 8% previously).
As it relates to non-cash costs, we increased our DD&A guidance to $10.50 - $10.75 per BOE from $10.00 - $10.75 previously and we reduced our non-cash G&A estimate for the year by another $0.05 per BOE to $0.30 - $0.40 per BOE.
Return of Capital:
We generated $1.4 billion of Net Cash Provided by Operating Activities ($1.5 billion after adjusting for working capital changes), $820 million of FCF and $884 million of adjusted FCF in the third quarter.
We repurchased 406,700 shares in the third quarter for a cost of $56 million ($136.59 / share average). Repurchase opportunities were limited in the third quarter, as commodity prices and our stock price rallied significantly. Therefore, we are planning to pay our base dividend of $0.84 / share and a variable dividend of $2.53 per share, or a total cash dividend of $3.37 per share for the quarter. So far in the fourth quarter, we took advantage of some early weakness in October to repurchase 217,900 shares at a cost of $32 million ($146.97 / share average).
As a reminder, we repurchase shares when we believe we can generate a low-teens rate of return on that repurchase at a Company Net Asset Value run at a mid-cycle price deck of $60 oil, $20 NGLs and $3 gas. Capital discipline is important in this industry, and we view returning capital to our stockholders through the same lens as allocating capital in the field. We would rather be conservative and err on the side of caution when buying back shares pro-cyclically, which is why we leaned into the variable dividend this quarter. There may come a time when we should direct all our FCF to buying back shares (after paying our base dividend), but that day is not today at current oil prices.
Balance Sheet:
Total debt and net debt decreased to just under $6.4 billion and $5.6 billion, respectively, in the third quarter, with net debt down over $1 billion from $6.7 billion in the second quarter. Consolidated net debt is now back to levels reached prior to the announcements of both the Lario and Firebird acquisitions late last year. We will continue to use 25% of our FCF to reduce debt at both Diamondback and Viper.
Non-core Asset Sale Update:
We have now announced and closed non-core asset sales for gross proceeds of approximately $1.7 billion, significantly exceeding our target of at least $1.0 billion of sales by year end 2023. While we still have significant value remaining in our portfolio of midstream assets that may be monetized at some point in the future, we are not going to increase our non-core asset sale target at this point.
In September, we announced a joint venture (“JV”) with Five Point Energy LLC (“Five Point”) that formed Deep Blue Midland Basin LLC (“Deep Blue”). This JV, of which Diamondback retained 30% ownership, creates the largest independent water business in the Midland Basin and brought in proceeds of ~$500 million to Diamondback. We are excited about the early commercial success of the JV, and believe there is significant potential for future growth in this business, both organic and inorganic. The Deep Blue team also brings expertise for the next wave of oilfield water management, including water recycling, enhanced evaporation and eventually desalination. The expected full-year financial impact of the JV will be a mix of higher LOE (~10% increase), significantly lower midstream capex (>75% decrease), reduced midstream operating expense and slightly higher well costs ($15 - $20 / lateral foot). All in all, we believe the upfront cash proceeds and potential for value creation at the JV far outweigh the go-forward financial impacts.
Other Business: Industry Consolidation
Industry consolidation has been a recurring theme in recent years as the shale industry has matured, and we are seeing an acceleration of that theme with the recent announcement of two significant transactions in the last month. While this is exciting for the industry, it does not change Diamondback’s business model or continued focus on executing on our business plan to create value for our stockholders, the owners of the Company.
Diamondback was built through an acquire and exploit strategy, where our execution prowess and low-cost structure allowed us to create value on acquired assets over the last decade. This remains our core competency as we believe the low-cost operator in a commodity-based business “wins”. We expect Diamondback to remain a consolidator in the future, and our underwriting criteria have not changed. A deal must meet the following criteria for it to make sense to Diamondback stockholders:
•Sound industrial logic (physical adjacencies, tangible cost and operations synergies)
•The assets compete for capital right away (get “better”, not just bigger)
•Accretive on financial metrics (CFPS, FCFPS, EPS)
We remain confident in our business model, the durability of our inventory and our ability to convert that inventory into cash flow efficiently for many years to come. We believe in the pure-play independent E&P business model, and know we can compete for investor capital in a consolidated space. While we recognize size and scale are being rewarded by the public markets, we have to get “better” when we get “bigger,” which we have proven through many acquisitions and subsequent execution over the years.
Thank you for your interest in Diamondback Energy,
Travis D. Stice
Chairman of the Board and Chief Executive Officer
Important Information Regarding Forward-Looking Statements and Non-GAAP Financial Measures
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 Securities Exchange Act of 1934, as amended, which involve risks, uncertainties and assumptions. Important information regarding forward-looking statements is included in our earnings release furnished to the SEC simultaneously with this letter.
This letter also contains certain Non-GAAP financial measures. For definitions and reconciliations of the Non-GAAP financial measures to the most directly comparable GAAP financial measures, please see our earnings release furnished to the SEC simultaneously with this letter.
Investor Contact:
Adam Lawlis
+1 432.221.7467
alawlis@diamondbackenergy.com