Crescent Energy narrows Q3 2026 net loss to $2.17M
The all-cash Eagle Ford acquisition is expected to close in the fourth quarter of 2026 or early 2027, subject to customary closing conditions.
Sentiment and the balance of points
Rhea-AI Sentiment reads the wording of the document, how positive or negative its language is on a 1 to 5 scale. The balance of points shown with the takes weighs what the document actually discloses, so the two can disagree, for example when a trial that missed its main goal is described in upbeat language.
Form Type
8-K
Rhea-AI Filing Summary
Crescent Energy Company (CRGY) reported third-quarter 2026 revenue of $1,351.212 million, compared with $866.579 million a year earlier. Net loss attributable to Crescent was $2.167 million, versus $9.507 million. Operating cash flow was $608.495 million, Adjusted EBITDAX was $785.829 million and Levered Free Cash Flow was $366.654 million; the latter two measures are non-GAAP. Production averaged 328 MBoe/d, including 134 MBo/d of oil.
In October 2026, Crescent announced an all-cash agreement to acquire Eagle Ford assets from Devon Energy for an estimated net purchase price of approximately $3.85 billion. The transaction is expected to close in the fourth quarter of 2026 or early 2027, subject to customary closing conditions. Crescent increased its Permian synergy target to more than $300 million and reported approximately $295 million captured to date, representing more than $1 billion of value creation on a five-year PV-10 basis.
Crescent declared a $0.12 per-share quarterly dividend, payable November 30, 2026, to shareholders of record November 16, 2026. It reported approximately $2.0 billion of liquidity, approximately 1.5x net leverage and no near-term maturities.
4 points · 0 major0 major · 0 points
How this balance works
Rhea-AI gives every point it takes from this document a weight. Minor counts 1, Moderate 3 and Major 9, so one Major point outweighs several Minor ones. The bar adds up the weights on each side, and when neither side holds more than 65% of the total the balance reads Mixed.
It reads the document as published, with the same rules for every company, and it does not look at what the market expected or at how the stock traded, so a point can be objectively good on a day the stock falls.
Rhea-AI Sentiment measures something else, the tone of the wording.
Positive
- Moderate pointThird-quarter revenue was $1,351.212 million, versus $866.579 million a year earlier.
- Moderate pointAdjusted EBITDAX was $785.829 million, versus $486.539 million a year earlier.
- Moderate pointOperating cash flow was $608.495 million, versus $473.060 million a year earlier.
- Moderate pointLevered Free Cash Flow was $366.654 million, versus $204.467 million a year earlier.
Negative
- None.
Filing Explained
Crescent’s repurchase program had
8-K Event Classification
3 items: 2.02, 7.01, 9.01
3 items
Item 2.02
Results of Operations and Financial Condition
Financial
Disclosure of earnings results, typically an earnings press release or preliminary financials.
Item 7.01
Regulation FD Disclosure
Disclosure
Material non-public information disclosed under Regulation Fair Disclosure, often investor presentations or guidance.
Item 9.01
Financial Statements and Exhibits
Exhibits
Financial statements, pro forma financial information, or exhibit attachments filed with this report.
Key Figures
Total revenue: $1,351.212 million
Net loss attributable to Crescent: Loss of $2.167 million
Adjusted EBITDAX: $785.829 million
+5 more
8 metrics
Total revenue
$1,351.212 million
Three months ended September 30, 2026; $866.579 million in 2025
Net loss attributable to Crescent
Loss of $2.167 million
Three months ended September 30, 2026; loss of $9.507 million in 2025
Adjusted EBITDAX
$785.829 million
Third quarter 2026; non-GAAP measure
Operating cash flow
$608.495 million
Third quarter 2026
Levered Free Cash Flow
$366.654 million
Third quarter 2026; non-GAAP measure
Production
328 MBoe/d
Third quarter 2026 average
Estimated net purchase price
Approximately $3.85 billion
All-cash Eagle Ford assets acquisition from Devon Energy
Quarterly dividend
$0.12 per share
Third quarter 2026 dividend
Key Terms
Adjusted EBITDAX, Levered Free Cash Flow, Net Leverage, PV-10
4 terms
Adjusted EBITDAX financial
"Adjusted EBITDAX is not a measure of performance as determined by GAAP"
Adjusted EBITDAX is a measure of a company’s operating profit that adds back interest, taxes, depreciation, amortization and specific recurring costs (often exploration or similar project expenses), then removes one‑time or unusual items to show recurring cash profitability. Investors use it like a clean yardstick—ignoring financing choices, accounting rules and one‑off events—to compare core performance across periods or peers and assess a business’s ability to generate cash from operations.
Levered Free Cash Flow financial
"Levered Free Cash Flow is not a measure of liquidity as determined by GAAP"
Levered free cash flow is the cash a company has left after paying all operating costs, taxes, interest and required debt repayments — essentially the money truly available to shareholders. For investors it matters because it shows whether a business can afford dividends, share buybacks, reinvestment or can weather a downturn after meeting its loan obligations; think of it like a household’s leftover money once the mortgage and other mandatory bills are paid.
Net Leverage financial
"Net Leverage is the ratio of consolidated total debt to consolidated Adjusted EBITDAX"
Net leverage measures how many years it would take for a company to pay off its outstanding debt using its annual operating cash flow, after subtracting cash on hand from total debt. Think of it like a household’s mortgage balance minus savings divided by yearly income; a lower number means the company is in a safer position to handle debt, while a higher number signals greater financial risk and potential pressure on profits or growth.
PV-10 financial
"Represents 5-year PV-10 of synergies captured to date"
PV-10 is a valuation metric that estimates the present value of future oil and gas production cash flows, discounted at 10% and stated before income taxes. Think of it as the current price tag on a company’s proven reserves, calculated by shrinking future revenue streams to today’s dollars using a 10% rate. Investors use PV-10 to compare the relative worth of reserves and assess how much future production could contribute to a company’s value, much like comparing the upfront price of different rental properties based on expected future rent.
Earnings Snapshot
Total revenue: $1,351.212 million
Third quarter 2026
Total revenue
$1,351.212 million
Compared with $866.579 million in the third quarter of 2025
Net loss attributable to Crescent
Loss of $2.167 million
Loss of $9.507 million in the third quarter of 2025
Adjusted EBITDAX
$785.829 million (non-GAAP)
Compared with $486.539 million in the third quarter of 2025
Operating cash flow
$608.495 million
Compared with $473.060 million in the third quarter of 2025
Levered Free Cash Flow
$366.654 million (non-GAAP)
Compared with $204.467 million in the third quarter of 2025
FAQ
AI-generated questions and answers. How Rhea-AI works. Not financial advice.
What were CRGY's third-quarter 2026 revenue and operating cash flow?
Crescent reported total revenue of $1,351.212 million for the third quarter of 2026, compared with $866.579 million for the third quarter of 2025. Operating cash flow was $608.495 million for the quarter.
What is CRGY's Devon Energy acquisition price and expected closing window?
Crescent described an all-cash transaction with an estimated net purchase price of approximately $3.85 billion. It expects closing in the fourth quarter of 2026 or early 2027, subject to customary closing conditions. The net purchase price is the headline purchase price less estimated purchase price adjustments, including allocations based on a July 1, 2026 effective date, and excludes transaction costs.
AI-generated analysis. How Rhea-AI works. Not financial advice.
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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
OF THE SECURITIES EXCHANGE ACT OF 1934
Date of report (Date of earliest event reported): November 2, 2026
(Exact Name of Registrant As Specified in Its Charter) | ||||||||
(State or Other Jurisdiction of Incorporation) | (Commission File Number) | (I.R.S. Employer Identification No.) | ||||||
(Address of Principal Executive Offices) | (Zip Code) | |||||||
( | ||||||||
Registrant’s Telephone Number, Including Area Code | ||||||||
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
Written communication pursuant to Rule 425 under the Securities Act of 1933 (17 CFR 230.425) | |||||
Soliciting material pursuant to Rule 14a-12 under the Securities Exchange Act of 1934 (17 CFR 240.14a-12) | |||||
Pre-commencement communication pursuant to Rule 14d-2(b) under the Securities Exchange Act of 1934 (17 CFR 240.14d-2(b)) | |||||
Pre-commencement communication pursuant to Rule 13e-4(c) under the Securities Exchange Act of 1934 (17 CFR 240.13e-4(c)) | |||||
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 | ||||||
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 Securities Exchange Act of 1934. ☐
Item 2.02. | Results of Operations and Financial Condition. | ||||
Earnings Release
On November 2, 2026, Crescent Energy Company (the “Company”) announced its financial and operating results for the quarter ended September 30, 2026. A copy of the Company’s press release is furnished as Exhibit 99.1 to this Current Report on Form 8-K and incorporated herein by reference.
The information contained in this Item 2.02, including the exhibit, shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to the liabilities of that section, and is not incorporated by reference into any filing under the Securities Act of 1933, as amended (the “Securities Act”), or the Exchange Act.
Item 7.01. Regulation FD Disclosure.
The information contained in Item 2.02 of this Current Report on Form 8-K is incorporated into this Item 7.01 by reference.
The information contained in this Item 7.01, including the exhibit, shall not be deemed to be “filed” for purposes of Section 18 of the Exchange Act, or otherwise subject to the liabilities of that section, and is not incorporated by reference into any filing under the Securities Act or the Exchange Act.
Item 9.01. Financial Statements and Exhibits.
(d) Exhibits.
Exhibit | Description | ||||
99.1 | Press release of Crescent Energy Company dated as of November 2, 2026. | ||||
104 | Cover Page Interactive Data File (embedded within the Inline XBRL document). | ||||
2
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 hereunto duly authorized.
Date: November 2, 2026
CRESCENT ENERGY COMPANY
By: /s/ Bo Shi
Name: Bo Shi
Title: General Counsel
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Exhibit 99.1
Crescent Energy Reports Third Quarter 2026 Results
Houston, November 2, 2026 – Crescent Energy Company (NYSE: CRGY) (“Crescent” or the “Company”), today announced financial and operating results for the third quarter of 2026. A supplemental slide deck can be found at www.crescentenergyco.com. The Company plans to host a conference call and webcast at 10 a.m. CT on Tuesday, November 3, 2026. Details can be found in this release.
Third Quarter 2026 Highlights
–Delivered strong financial and operating performance, exceeding expectations across all key metrics
–Generated Operating Cash Flow of $608 million and Levered Free Cash Flow(1) of $367 million, supporting deleveraging and shareholder returns
–Produced 328 MBoe/d, including 134 MBo/d of oil, driven by consistent execution across the portfolio
–Increased the Permian synergy target to more than $300 million, with approximately $295 million captured to date, representing more than $1 billion of value creation(2)
–Drove Permian marketing and midstream optimization efforts to reduce costs, expand access to premium Gulf Coast markets and achieve higher realizations and incremental free cash flow
–Expanded economic inventory with lower well costs across the portfolio
–Announced the acquisition of premier Eagle Ford assets from Devon Energy, expanding Crescent’s world-class Eagle Ford position with significant Tier 1 inventory that immediately competes for capital
–Maintained a strong balance sheet, with approximately $2.0 billion of liquidity, approximately 1.5x leverage and no near-term maturities
–Declared a fixed quarterly dividend of $0.12 per share
“Our market-leading operational execution continues to drive strong results and differentiated value creation. We delivered higher production, lower capital and higher free cash flow than market expectations this quarter,” said Crescent CEO David Rockecharlie. “We have assembled an exceptional asset base, anchored by a world-class Eagle Ford position, alongside significant opportunities across the Permian, Uinta and Crescent Royalties. Importantly, the next phase of Crescent’s value creation is largely within our control. Our focus is on execution.”
Third Quarter 2026 Financial and Operating Results
Third quarter production averaged 328 MBoe/d (approximately 41% oil and 63% liquids), with 134 MBo/d of oil production. The Company drilled 29 gross operated wells (22 in the Eagle Ford, 6 in the Permian and 1 in the Uinta), brought online 37 gross operated wells (25 in the Eagle Ford, 5 in the Permian and 7 in the Uinta) and incurred capital expenditures (excluding acquisitions) of $326 million during the third quarter.
Crescent reported $1 million of net loss and $254 million of Adjusted Net Income(1) in the third quarter. The Company generated Adjusted EBITDAX(1) of $786 million, Operating Cash Flow of $608 million and Levered Free Cash Flow(1) of $367 million for the period, supported by disciplined capital investment and strong operational execution.
Permian Optimization
1
Crescent continued to advance the optimization of the Permian assets during the third quarter. Based on accelerated synergy capture and continued operating improvements, the Company increased its synergy target to more than $300 million, with approximately $295 million captured to date, representing more than $1 billion of value creation.(2)
Announced Eagle Ford Acquisition
In October 2026, Crescent announced that it had entered into a definitive agreement to acquire Eagle Ford assets from Devon Energy for an estimated net purchase price of approximately $3.85 billion(3) (the “Transaction”). The all-cash Transaction solidifies Crescent’s world-class Eagle Ford position, adding Tier 1 inventory and meaningful scale directly adjacent to its existing operations. The Transaction is expected to close in the fourth quarter of 2026 or early 2027, subject to customary closing conditions.
Shareholder Return
Crescent’s long-standing “all-of-the-above” return of capital framework includes a fixed quarterly dividend and an opportunistic share repurchase program. For the third quarter of 2026, the Company’s Board of Directors (the “Board”) approved a cash dividend of $0.12 per share. The third quarter dividend is payable on November 30, 2026, to shareholders of record as of the close of business on November 16, 2026. Any payment of future dividends is subject to Board approval and other factors.
As of September 30, 2026, our share repurchase program (the “Share Repurchase Program”) has approximately $336 million of availability remaining. Repurchases of shares of the Company’s common stock under the Share Repurchase Program may be made by the Company from time to time in the open market, in a privately negotiated transaction, through purchases made in accordance with Rule 10b5-1 of the Securities Exchange Act of 1934, as amended, or by such other means as will comply with applicable state and federal securities laws. The timing of any such repurchases will depend on market conditions, contractual limitations and other considerations. The program may be extended, modified, suspended or discontinued at any time, and does not obligate the Company to repurchase any dollar amount or number of shares.
Conference Call Information
Crescent plans to host a conference call to discuss its third quarter of 2026 financial and operating results at 10 a.m. CT on Tuesday, November 3, 2026. Complete details are below. A webcast replay will be available on the website following the call.
Date: Tuesday, November 3, 2026
Time: 10 a.m. CT (11 a.m. ET)
Conference Dial-In: 833-461-5787 / 585-542-9983 (Domestic / International)
Meeting ID: 360 772 191
Webcast Link: www.crescentenergyco.com
About Crescent Energy Company
Crescent is a differentiated energy company committed to delivering value through a disciplined, returns-driven growth through acquisition strategy and consistent return of capital. Our long-life, balanced portfolio combines significant cash flow from stable production with deep, high-quality development inventory. Our activities are focused in the Eagle Ford, Permian and Uinta Basins, and we own minerals and royalty interests
2
across premier U.S. oil and natural gas basins, primarily operated by large, well-capitalized companies, with a core focus in the Eagle Ford. For additional information, please visit www.crescentenergyco.com.
Cautionary Statement Regarding Forward-Looking Statements
The foregoing 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. All statements, other than statements of historical fact, included in this communication that address activities, events or developments that Crescent expects, believes or anticipates will or may occur in the future are forward-looking statements. Words such as “estimate,” “project,” “predict,” “believe,” “expect,” “anticipate,” “potential,” “create,” “intend,” “could,” “may,” “foresee,” “plan,” “will,” “guidance,” “look,” “outlook,” “goal,” “future,” “assume,” “forecast,” “build,” “focus,” “work,” “continue” or the negative of such terms or other variations thereof and words and terms of similar substance used in connection with any discussion of future plans, actions, or events identify forward-looking statements. However, the absence of these words does not mean that the statements are not forward-looking. These forward-looking statements include, but are not limited to, statements regarding our ability to integrate operations or realize any anticipated operational or corporate synergies and other benefits of our acquisitions, including the acquisition of Vital Energy, Inc. (the “Permian Acquisition”) and, if completed, the Transaction; the risk that the Permian Acquisition and, if completed, the Transaction may not be accretive, and may be dilutive, to Crescent’s earnings per share, which may negatively affect the market price of Crescent common stock; the risk that the Transaction may not be completed on the terms currently contemplated, in the anticipated timeframe or at all; risks related to disruption of management time from ongoing business operations due to the Transaction; the risk that any announcements relating to the Transaction could have adverse effects on the market price of Crescent common stock; our ability to identify and select opportunities for additional acquisitions, dispositions and other strategic transactions; federal and state regulations and laws, including those relating to taxes (including the One Big Beautiful Bill Act and the Inflation Reduction Act of 2022), tariffs and international trade, safety and the protection of the environment and the impact thereof on us; general economic conditions, including the impact of inflation, elevated interest rates and associated changes in monetary policy; the impact of central bank policy actions, including any changes in interest rates, any changes in its policy priorities, and disruptions in the banking industry and capital markets; political and economic conditions and events in the U.S. and in foreign oil, natural gas and natural gas liquids (“NGL”) producing countries, including embargoes, political and regulatory changes implemented by the Trump Administration, continued hostilities in the Middle East, including the Israel-Hamas conflict and the conflict with Iran, and other sustained military campaigns, the armed conflict in Ukraine and associated economic sanctions on Russia, conditions and developments in South America and in China and acts of terrorism or sabotage; our ability to predict and manage the effects of actions of Organization of Petroleum Exporting Countries and its allies and agreements to set and maintain production levels, including compliance with, changes to or departures from such arrangements, the effects of which may be exacerbated by the continued hostilities in the Middle East, including with Iran, and developments in Venezuela and other major oil-producing countries; and the severity and duration of public health crises and any resultant impact on governmental actions, commodity prices, supply and demand considerations, and storage capacity. Consequently, actual future results could differ materially from expectations. The Company assumes no duty to update or revise its respective forward-looking statements based on new information, future events or otherwise.
Financial Presentation
We have evaluated how we are organized and managed and have identified one reportable segment, which is our interests related to the exploration and production of crude oil, natural gas and NGLs from operated and
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non-operated wells. We consider our gathering, processing and marketing functions as ancillary to our oil and gas producing activities. Substantially all of our operations and assets are located onshore in the United States, and substantially all of our revenues are attributable to United States customers. We present certain operational results for Crescent Royalty Finance LLC (“CRF”) separately from the Crescent Energy Finance LLC (“CEF”) operational results because we believe that it permits investors to better understand the performance of this aspect of our business. The financial and operating information presented herein does not give effect to the Transaction.
Crescent Operational Summary
| For the three months ended | |||||||||||||||||
| September 30, 2026 | September 30, 2025 | June 30, 2026 | |||||||||||||||
Total Consolidated | |||||||||||||||||
| Average daily net sales volumes: | |||||||||||||||||
| Oil (MBbls/d) | 134 | 103 | 140 | ||||||||||||||
| Natural gas (MMcf/d) | 716 | 631 | 715 | ||||||||||||||
| NGLs (MBbls/d) | 74 | 45 | 76 | ||||||||||||||
| Total (MBoe/d) | 328 | 253 | 335 | ||||||||||||||
| Average realized prices, before effects of derivative settlements: | |||||||||||||||||
| Oil ($/Bbl) | $ | 84.52 | $ | 63.07 | $ | 96.61 | |||||||||||
| Natural gas ($/Mcf) | 2.35 | 2.49 | 0.52 | ||||||||||||||
| NGLs ($/Bbl) | 20.58 | 22.53 | 18.67 | ||||||||||||||
| Total ($/Boe) | 44.38 | 35.87 | 45.63 | ||||||||||||||
| Average realized prices, after effects of derivative settlements: | |||||||||||||||||
| Oil ($/Bbl) | $ | 71.55 | $ | 64.93 | $ | 73.33 | |||||||||||
| Natural gas ($/Mcf) | 2.70 | 2.56 | 1.74 | ||||||||||||||
| NGLs ($/Bbl) | 20.58 | 22.57 | 18.67 | ||||||||||||||
Total ($/Boe)(4) | 39.84 | 36.81 | 38.52 | ||||||||||||||
| Expense (per Boe) | |||||||||||||||||
| Operating expense | $ | 14.41 | $ | 16.65 | $ | 13.38 | |||||||||||
| Depreciation, depletion and amortization | 12.44 | 12.84 | 11.75 | ||||||||||||||
| General and administrative expense | 2.17 | 3.20 | 2.02 | ||||||||||||||
| Non-GAAP and other expense (per Boe) | |||||||||||||||||
Adjusted operating expense, excluding production and other taxes(1)(5) | $ | 11.35 | $ | 12.83 | $ | 10.95 | |||||||||||
| Production and other taxes | 2.60 | 2.39 | 2.27 | ||||||||||||||
Adjusted Recurring Cash G&A(1) | 1.32 | 1.33 | 1.26 | ||||||||||||||
4
| For the three months ended | |||||||||||||||||
| September 30, 2026 | September 30, 2025 | June 30, 2026 | |||||||||||||||
| Working interest | |||||||||||||||||
| Average daily net sales volumes: | |||||||||||||||||
| Oil (MBbls/d) | 129 | 101 | 133 | ||||||||||||||
| Natural gas (MMcf/d) | 692 | 603 | 685 | ||||||||||||||
| NGLs (MBbls/d) | 72 | 44 | 74 | ||||||||||||||
| Total (MBoe/d) | 317 | 245 | 322 | ||||||||||||||
| Average realized prices, before effects of derivative settlements: | |||||||||||||||||
| Oil ($/Bbl) | $ | 84.26 | $ | 63.08 | $ | 96.78 | |||||||||||
| Natural gas ($/Mcf) | 2.35 | 2.49 | 0.46 | ||||||||||||||
| NGLs ($/Bbl) | 20.29 | 22.49 | 18.41 | ||||||||||||||
| Total ($/Boe) | 44.10 | 36.07 | 45.38 | ||||||||||||||
| Average realized prices, after effects of derivative settlements: | |||||||||||||||||
| Oil ($/Bbl) | $ | 71.34 | $ | 64.99 | $ | 73.14 | |||||||||||
| Natural gas ($/Mcf) | 2.67 | 2.56 | 1.69 | ||||||||||||||
| NGLs ($/Bbl) | 20.29 | 22.53 | 18.41 | ||||||||||||||
| Total ($/Boe) | 39.55 | 37.04 | 38.20 | ||||||||||||||
| Expense (per Boe) | |||||||||||||||||
| Operating expense | $ | 14.81 | $ | 17.18 | $ | 13.76 | |||||||||||
| For the three months ended | |||||||||||||||||
| September 30, 2026 | September 30, 2025 | June 30, 2026 | |||||||||||||||
| Minerals and royalties | |||||||||||||||||
| Average daily net sales volumes: | |||||||||||||||||
| Oil (MBbls/d) | 5 | 2 | 6 | ||||||||||||||
| Natural gas (MMcf/d) | 24 | 28 | 30 | ||||||||||||||
| NGLs (MBbls/d) | 2 | 1 | 2 | ||||||||||||||
| Total (MBoe/d) | 11 | 8 | 13 | ||||||||||||||
| Average realized prices, before effects of derivative settlements: | |||||||||||||||||
| Oil ($/Bbl) | $ | 90.91 | $ | 62.28 | $ | 92.88 | |||||||||||
| Natural gas ($/Mcf) | 2.27 | 2.49 | 1.92 | ||||||||||||||
| NGLs ($/Bbl) | 30.03 | 24.17 | 27.13 | ||||||||||||||
| Total ($/Boe) | 52.03 | 29.71 | 51.45 | ||||||||||||||
| Average realized prices, after effects of derivative settlements: | |||||||||||||||||
| Oil ($/Bbl) | $ | 76.60 | $ | 62.28 | $ | 77.45 | |||||||||||
| Natural gas ($/Mcf) | 3.30 | 2.49 | 2.80 | ||||||||||||||
| NGLs ($/Bbl) | 30.08 | 24.17 | 27.06 | ||||||||||||||
| Total ($/Boe) | 47.72 | 29.71 | 46.31 | ||||||||||||||
| Expense (per Boe) | |||||||||||||||||
| Operating expense | $ | 3.35 | $ | 0.41 | $ | 4.26 | |||||||||||
5
Crescent Condensed Consolidated Statements of Operations
| (Unaudited) | |||||||||||||||||||||||
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| (in thousands, except per share data) | 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||
| Revenues: | |||||||||||||||||||||||
| Oil | $ | 1,042,500 | $ | 596,288 | $ | 3,162,646 | $ | 1,818,435 | |||||||||||||||
| Natural gas | 154,593 | 144,462 | 346,734 | 490,903 | |||||||||||||||||||
| Natural gas liquids | 140,345 | 92,589 | 394,823 | 298,306 | |||||||||||||||||||
| Midstream and other | 13,774 | 33,240 | 24,793 | 107,091 | |||||||||||||||||||
| Total revenues | 1,351,212 | 866,579 | 3,928,996 | 2,714,735 | |||||||||||||||||||
| Expenses: | |||||||||||||||||||||||
| Lease and asset operating expense | 229,393 | 187,125 | 670,671 | 559,594 | |||||||||||||||||||
| Workover expense | 30,886 | 23,105 | 94,131 | 58,486 | |||||||||||||||||||
| Gathering, processing and transportation | 90,190 | 93,427 | 286,744 | 304,789 | |||||||||||||||||||
| Production and other taxes | 78,412 | 55,430 | 203,119 | 170,917 | |||||||||||||||||||
| Depreciation, depletion and amortization | 374,895 | 298,450 | 1,087,024 | 878,079 | |||||||||||||||||||
| Impairment of oil and natural gas properties | — | 73,527 | — | 122,159 | |||||||||||||||||||
| Exploration expense | 4,225 | 1,002 | 11,110 | 6,882 | |||||||||||||||||||
| Midstream and other operating expense | 5,312 | 27,796 | 16,216 | 86,639 | |||||||||||||||||||
| General and administrative expense | 65,275 | 74,275 | 189,569 | 255,657 | |||||||||||||||||||
| (Gain) loss on sale of assets | (6,065) | 1,641 | (16,755) | (11,131) | |||||||||||||||||||
| Total expenses | 872,523 | 835,778 | 2,541,829 | 2,432,071 | |||||||||||||||||||
| Income (loss) from operations | 478,689 | 30,801 | 1,387,167 | 282,664 | |||||||||||||||||||
| Other income (expense): | |||||||||||||||||||||||
| Gain (loss) on derivatives | (405,833) | 55,702 | (930,541) | 163,259 | |||||||||||||||||||
| Interest expense | (94,214) | (72,629) | (298,611) | (221,029) | |||||||||||||||||||
| Loss from extinguishment of debt | (16) | (29,248) | (17,413) | (29,248) | |||||||||||||||||||
| Other income (expense) | 26,427 | 209 | 26,571 | 440 | |||||||||||||||||||
| Income (loss) from equity affiliates | 339 | 864 | 395 | 1,695 | |||||||||||||||||||
| Total other income (expense) | (473,297) | (45,102) | (1,219,599) | (84,883) | |||||||||||||||||||
| Income (loss) before taxes | 5,392 | (14,301) | 167,568 | 197,781 | |||||||||||||||||||
| Income tax benefit (expense) | (5,983) | 4,032 | (93,631) | (39,638) | |||||||||||||||||||
| Net income (loss) | (591) | (10,269) | 73,937 | 158,143 | |||||||||||||||||||
| Less: net (income) loss attributable to noncontrolling interests | (1,576) | 762 | (3,186) | (2,526) | |||||||||||||||||||
| Less: net (income) loss attributable to redeemable noncontrolling interests | — | — | — | (14,050) | |||||||||||||||||||
| Net income (loss) attributable to Crescent | $ | (2,167) | $ | (9,507) | $ | 70,751 | $ | 141,567 | |||||||||||||||
| Net income (loss) per share: | |||||||||||||||||||||||
| Class A common stock – basic | $ | (0.01) | $ | (0.04) | $ | 0.21 | $ | 0.61 | |||||||||||||||
| Class A common stock – diluted | $ | (0.01) | $ | (0.04) | $ | 0.21 | $ | 0.60 | |||||||||||||||
| Class B common stock – basic and diluted | $ | — | $ | — | $ | — | $ | — | |||||||||||||||
| Weighted average shares outstanding: | |||||||||||||||||||||||
| Class A common stock – basic | 330,421 | 254,621 | 329,667 | 233,261 | |||||||||||||||||||
| Class A common stock – diluted | 330,421 | 254,621 | 341,749 | 236,029 | |||||||||||||||||||
| Class B common stock – basic and diluted | — | — | — | 22,207 | |||||||||||||||||||
6
Crescent Condensed Consolidated Balance Sheets | |||||||||||
(Unaudited) | |||||||||||
| September 30, 2026 | December 31, 2025 | ||||||||||
| (in thousands, except share data) | |||||||||||
| ASSETS | |||||||||||
| Current assets: | |||||||||||
| Cash and cash equivalents | $ | 6,126 | $ | 10,157 | |||||||
| Restricted cash | 5,506 | 725,702 | |||||||||
| Accounts receivable, net | 768,503 | 738,333 | |||||||||
| Accounts receivable – affiliates | 10,268 | 4,501 | |||||||||
| Derivative assets – current | 3,592 | 322,784 | |||||||||
| Prepaid expenses | 41,629 | 46,309 | |||||||||
| Other current assets | 84,982 | 13,271 | |||||||||
| Total current assets | 920,606 | 1,861,057 | |||||||||
| Property, plant and equipment: | |||||||||||
| Oil and natural gas properties at cost, successful efforts method | |||||||||||
| Proved | 14,513,195 | 13,264,097 | |||||||||
| Unproved | 512,857 | 413,444 | |||||||||
| Oil and natural gas properties at cost, successful efforts method | 15,026,052 | 13,677,541 | |||||||||
| Field and other property and equipment, at cost | 174,451 | 157,031 | |||||||||
| Total property, plant and equipment | 15,200,503 | 13,834,572 | |||||||||
| Less: accumulated depreciation, depletion, amortization and impairment | (4,610,514) | (3,558,601) | |||||||||
| Property, plant and equipment, net | 10,589,989 | 10,275,971 | |||||||||
| Derivative assets – noncurrent | 9,273 | 2,829 | |||||||||
| Investments in equity affiliates | 10,466 | 8,146 | |||||||||
| Deferred tax asset | 71,465 | 143,706 | |||||||||
| Other assets | 157,417 | 151,498 | |||||||||
| TOTAL ASSETS | $ | 11,759,216 | $ | 12,443,207 | |||||||
7
Crescent Condensed Consolidated Balance Sheets | |||||||||||
(Unaudited) | |||||||||||
| September 30, 2026 | December 31, 2025 | ||||||||||
| (in thousands, except share data) | |||||||||||
| LIABILITIES AND EQUITY | |||||||||||
| Current liabilities: | |||||||||||
| Accounts payable and accrued liabilities | $ | 1,010,370 | $ | 1,121,678 | |||||||
| Accounts payable – affiliates | 19,948 | 46,279 | |||||||||
| Derivative liabilities – current | 233,726 | — | |||||||||
| Financing lease obligations – current | 4,066 | 4,860 | |||||||||
| Other current liabilities | 110,439 | 86,603 | |||||||||
| Total current liabilities | 1,378,549 | 1,259,420 | |||||||||
| Long-term debt | 4,717,703 | 5,524,128 | |||||||||
| Derivative liabilities – noncurrent | 21,067 | 13,421 | |||||||||
| Asset retirement obligations | 387,094 | 383,057 | |||||||||
| Deferred tax liability | 16,375 | 11,671 | |||||||||
| Financing lease obligations – noncurrent | 1,027 | 3,228 | |||||||||
| Other liabilities | 101,276 | 82,847 | |||||||||
| Total liabilities | 6,623,091 | 7,277,772 | |||||||||
| Commitments and contingencies | |||||||||||
| Equity: | |||||||||||
Class A common stock, $0.0001 par value; 1,000,000,000 shares authorized, 337,664,962 and 334,979,293 shares issued, 330,456,708 and 327,900,272 shares outstanding as of September 30, 2026 and December 31, 2025, respectively. | 33 | 33 | |||||||||
| Class B common stock, $0.0001 par value; 500,000,000 shares authorized as of September 30, 2026 and December 31, 2025. | — | — | |||||||||
| Preferred stock, $0.0001 par value; 500,000,000 shares authorized and 1,000 Series I preferred shares issued and outstanding as of September 30, 2026 and December 31, 2025. | — | — | |||||||||
| Treasury stock, at cost; 7,208,254 and 7,079,021 shares of Class A common stock as of September 30, 2026 and December 31, 2025, respectively. | (72,690) | (71,054) | |||||||||
| Additional paid-in capital | 5,200,121 | 5,228,928 | |||||||||
| Retained earnings (accumulated deficit) | — | — | |||||||||
| Noncontrolling interests | 8,661 | 7,528 | |||||||||
| Total equity | 5,136,125 | 5,165,435 | |||||||||
| TOTAL LIABILITIES AND EQUITY | $ | 11,759,216 | $ | 12,443,207 | |||||||
8
Crescent Condensed Consolidated Statements of Cash Flows
| (Unaudited) | |||||||||||
| Nine Months Ended September 30, | |||||||||||
| 2026 | 2025 | ||||||||||
| Cash flows from operating activities: | |||||||||||
| Net income (loss) | $ | 73,937 | $ | 158,143 | |||||||
| Adjustments to reconcile net income (loss) to net cash provided by operating activities | |||||||||||
| Depreciation, depletion and amortization | 1,087,024 | 878,079 | |||||||||
| Impairment expense | — | 122,159 | |||||||||
| Deferred tax expense (benefit) | 89,339 | 36,832 | |||||||||
| (Gain) loss on derivatives | 930,541 | (163,259) | |||||||||
| Net cash (paid) received on settlement of derivatives | (504,029) | 31,038 | |||||||||
| Non-cash equity-based compensation expense | 65,482 | 143,281 | |||||||||
| Amortization of debt issuance costs, premium and discount | 12,491 | 11,161 | |||||||||
| Loss from debt extinguishment | 17,413 | 29,248 | |||||||||
| (Gain) loss on sale of oil and natural gas properties | (16,755) | (11,131) | |||||||||
| Settlement of acquired derivative contracts | 156,332 | 49,580 | |||||||||
| Other | (18,993) | (28,248) | |||||||||
Changes in operating assets and liabilities | (168,308) | 52,257 | |||||||||
| Net cash provided by operating activities | 1,724,474 | 1,309,140 | |||||||||
| Cash flows from investing activities: | |||||||||||
| Development of oil and natural gas properties | (1,019,827) | (691,373) | |||||||||
| Acquisitions of oil and natural gas properties, net of cash acquired | (359,233) | (942,465) | |||||||||
| Proceeds from the sale of oil and natural gas properties | 28,834 | 114,799 | |||||||||
| Purchases of restricted investment securities – HTM | (21,887) | (16,158) | |||||||||
| Maturities of restricted investment securities – HTM | 21,939 | 16,168 | |||||||||
| Other | (11,661) | — | |||||||||
| Net cash used in investing activities | (1,361,835) | (1,519,029) | |||||||||
| Cash flows from financing activities: | |||||||||||
| Proceeds from the issuance of Senior Notes, after premium, discount and underwriting fees | 671,025 | 591,750 | |||||||||
2031 Convertible Notes capped call | (56,649) | — | |||||||||
| Repurchase of Senior Notes, including extinguishment costs | (810,261) | (522,360) | |||||||||
| Revolving Credit Facility borrowings | 3,487,000 | 2,735,000 | |||||||||
| Revolving Credit Facility repayments | (4,259,648) | (2,663,000) | |||||||||
CRF Credit Facility borrowings | 305,000 | — | |||||||||
CRF Credit Facility repayments | (221,500) | — | |||||||||
Proceeds from issuance of CRF Term Loan | 135,000 | — | |||||||||
Repayments of CRF Term Loan | (135,000) | — | |||||||||
| Payment of debt issuance costs | (10,150) | (6,319) | |||||||||
Settlement of Ridgemar contingent earn-out consideration | (35,295) | — | |||||||||
Dividends | (118,627) | (84,565) | |||||||||
Distributions to redeemable noncontrolling interests | — | (17,192) | |||||||||
| Repurchase of noncontrolling interest | (32,196) | — | |||||||||
| Noncontrolling interest distributions | (2,402) | (4,150) | |||||||||
| Cash paid for treasury stock acquired for equity-based compensation tax withholding | (1,635) | (58) | |||||||||
| Repurchases of Class A common stock | — | (33,828) | |||||||||
| Other | — | (2,846) | |||||||||
| Net cash provided by (used in) financing activities | (1,085,338) | (7,568) | |||||||||
| Net change in cash, cash equivalents and restricted cash | (722,699) | (217,457) | |||||||||
| Cash, cash equivalents and restricted cash, beginning of period | 753,310 | 240,908 | |||||||||
| Cash, cash equivalents and restricted cash, end of period | $ | 30,611 | $ | 23,451 | |||||||
9
Reconciliation of Non-GAAP Measures
This release includes financial measures that have not been calculated in accordance with U.S. generally accepted accounting principles (“GAAP”). These non-GAAP measures include Adjusted EBITDAX, Levered Free Cash Flow, Adjusted Net Income, Adjusted Recurring Cash G&A and Net Leverage. These supplemental non-GAAP performance measures are used by Crescent’s management and external users of its financial statements, such as industry analysts, investors, lenders and rating agencies. These non-GAAP measures should be read in conjunction with the information contained in Crescent’s audited combined and consolidated financial statements prepared in accordance with GAAP.
Adjusted EBITDAX and Levered Free Cash Flow
We define Adjusted EBITDAX as net income (loss) before interest expense, loss from extinguishment of debt, income tax expense (benefit), depreciation, depletion and amortization, exploration expense, non-cash gain (loss) on derivatives, impairment expense, equity-based compensation, (gain) loss on sale of assets, other (income) expense and transaction and nonrecurring expenses. Additionally, we further adjust for certain redeemable noncontrolling interest distributions made by Crescent Energy OpCo LLC (“OpCo”) and settlement of acquired derivative contracts. We included certain redeemable noncontrolling interest distributions made by OpCo to reflect Manager Compensation as if 100% of OpCo were owned and managed by the Company, to reflect consistent earnings and liquidity measures not impacted by the amount of OpCo’s ownership under management. After giving effect to the Corporate Simplification, the Company owns 100% of outstanding OpCo Units and no longer makes distributions to the holders of redeemable noncontrolling interests in OpCo.
Adjusted EBITDAX is not a measure of performance as determined by GAAP. We believe Adjusted EBITDAX is a useful performance measure because it allows for an effective evaluation of our operating performance when compared against our peers, without regard to our financing methods, corporate form or capital structure. We exclude the items listed above from net income (loss) in arriving at Adjusted EBITDAX because these amounts can vary substantially within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDAX should not be considered as an alternative to, or more meaningful than, net income (loss) as determined in accordance with GAAP, of which such measure is the most comparable GAAP measure. Certain items excluded from Adjusted EBITDAX are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax burden, as well as the historic costs of depreciable assets, none of which are reflected in Adjusted EBITDAX. Our presentation of Adjusted EBITDAX should not be construed as an inference that our results will be unaffected by unusual or nonrecurring items. Our computations of Adjusted EBITDAX may not be identical to other similarly titled measures of other companies. In addition, our revolving credit facility (the “Revolving Credit Facility”) and our outstanding senior notes (collectively, the “Senior Notes”) include a calculation of Adjusted EBITDAX for purposes of covenant compliance.
We define Levered Free Cash Flow as Adjusted EBITDAX less interest expense, excluding non-cash amortization of deferred financing costs, discounts and premiums, loss from extinguishment of debt, excluding non-cash write-off of deferred financing costs, discounts and premiums, current income tax benefit (expense), tax-related redeemable noncontrolling interest distributions made by OpCo and development of oil and natural gas properties. Levered Free Cash Flow does not take into account amounts incurred on acquisitions.
Levered Free Cash Flow is not a measure of liquidity as determined by GAAP. Levered Free Cash Flow is a supplemental non-GAAP liquidity measure that is used by our management and external users of our financial
10
statements, such as industry analysts, investors, lenders and rating agencies. We believe Levered Free Cash Flow is a useful liquidity measure because it allows for an effective evaluation of our operating and financial performance and the ability of our operations to generate cash flow that is available to reduce leverage or distribute to our equity holders. Levered Free Cash Flow should not be considered as an alternative to, or more meaningful than, Net cash flow provided by operating activities as determined in accordance with GAAP, of which such measure is the most comparable GAAP measure, or as an indicator of actual liquidity, operating performance or investing activities. Our computations of Levered Free Cash Flow may not be comparable to other similarly titled measures of other companies.
The following table presents a reconciliation of Adjusted EBITDAX (non-GAAP) and Levered Free Cash Flow (non-GAAP) to net income (loss) and Levered Free Cash Flow (non-GAAP) to Net cash provided by operating activities, the most directly comparable financial measure, respectively, calculated in accordance with GAAP:
11
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| (in thousands) | |||||||||||||||||||||||
| Net income (loss) | $ | (591) | $ | (10,269) | $ | 73,937 | $ | 158,143 | |||||||||||||||
| Adjustments to reconcile to Adjusted EBITDAX: | |||||||||||||||||||||||
| Interest expense | 94,214 | 72,629 | 298,611 | 221,029 | |||||||||||||||||||
| Loss from extinguishment of debt | 16 | 29,248 | 17,413 | 29,248 | |||||||||||||||||||
| Income tax expense (benefit) | 5,983 | (4,032) | 93,631 | 39,638 | |||||||||||||||||||
| Depreciation, depletion and amortization | 374,895 | 298,450 | 1,087,024 | 878,079 | |||||||||||||||||||
| Exploration expense | 4,225 | 1,002 | 11,110 | 6,882 | |||||||||||||||||||
| Non-cash (gain) loss on derivatives | 244,973 | (33,859) | 426,512 | (132,221) | |||||||||||||||||||
| Impairment expense | — | 73,527 | — | 122,159 | |||||||||||||||||||
| Non-cash equity-based compensation expense | 20,773 | 23,788 | 65,482 | 143,281 | |||||||||||||||||||
| (Gain) loss on sale of assets | (6,065) | 1,641 | (16,755) | (11,131) | |||||||||||||||||||
| Other (income) expense | (26,427) | (209) | (26,571) | (440) | |||||||||||||||||||
| Certain RNCI Distributions made by OpCo | — | — | — | (4,242) | |||||||||||||||||||
Transaction and nonrecurring expenses(6) | 40,133 | 19,938 | 86,774 | 29,844 | |||||||||||||||||||
Settlement of acquired derivative contracts(7) | 33,700 | 14,685 | 156,332 | 49,580 | |||||||||||||||||||
| Adjusted EBITDAX (non-GAAP) | $ | 785,829 | $ | 486,539 | $ | 2,273,500 | $ | 1,529,849 | |||||||||||||||
| Working interest and other Adjusted EBITDAX | $ | 741,965 | $ | 463,751 | $ | 2,146,016 | $ | 1,473,064 | |||||||||||||||
| Minerals and royalties Adjusted EBITDAX | $ | 43,864 | $ | 22,788 | $ | 127,484 | $ | 56,785 | |||||||||||||||
| Adjustments to reconcile to Levered Free Cash Flow: | |||||||||||||||||||||||
| Interest expense, excluding non-cash amortization of deferred financing costs, discounts, and premiums | (89,956) | (69,009) | (286,120) | (209,868) | |||||||||||||||||||
| Loss from extinguishment of debt, excluding non-cash write-off of deferred financing costs, discounts, and premiums | (16) | (22,360) | (11,979) | (22,360) | |||||||||||||||||||
| Current income tax benefit (expense) | (3,113) | 14,680 | (4,292) | (2,806) | |||||||||||||||||||
| Tax-related RNCI Distributions made by OpCo | — | (605) | — | (865) | |||||||||||||||||||
| Development of oil and natural gas properties | (326,090) | (204,778) | (994,938) | (677,031) | |||||||||||||||||||
| Levered Free Cash Flow (non-GAAP) | $ | 366,654 | $ | 204,467 | $ | 976,171 | $ | 616,919 | |||||||||||||||
| Working interest and other Levered Free Cash Flow | $ | 325,104 | $ | 181,679 | $ | 858,673 | $ | 560,079 | |||||||||||||||
| Minerals and royalties Levered Free Cash Flow | $ | 41,550 | $ | 22,788 | $ | 117,498 | $ | 56,840 | |||||||||||||||
12
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| (in thousands) | |||||||||||||||||||||||
| Net cash provided by operating activities | $ | 608,495 | $ | 473,060 | $ | 1,724,474 | $ | 1,309,140 | |||||||||||||||
| Changes in operating assets and liabilities | 60,751 | (74,015) | 168,308 | (52,257) | |||||||||||||||||||
| Certain RNCI Distributions made by OpCo | — | — | — | (4,242) | |||||||||||||||||||
| Tax-related RNCI Distributions made by OpCo | — | (605) | — | (865) | |||||||||||||||||||
Transaction and nonrecurring expenses(6) | 40,133 | 19,938 | 86,774 | 29,844 | |||||||||||||||||||
| Loss from extinguishment of debt, excluding non-cash write-off of deferred financing costs, discounts, and premiums | (16) | (22,360) | (11,979) | (22,360) | |||||||||||||||||||
| Exploration expense | 4,225 | 1,002 | 11,110 | 6,882 | |||||||||||||||||||
| Other adjustments and operating activities | (20,844) | 12,225 | (7,578) | 27,808 | |||||||||||||||||||
| Development of oil and natural gas properties | (326,090) | (204,778) | (994,938) | (677,031) | |||||||||||||||||||
| Levered Free Cash Flow (non-GAAP) | $ | 366,654 | $ | 204,467 | $ | 976,171 | $ | 616,919 | |||||||||||||||
Adjusted Net Income
Crescent defines Adjusted Net Income as net income (loss), adjusted for certain items. Management believes that Adjusted Net Income is useful to investors in evaluating operational trends of the Company and its performance relative to other oil and gas companies. Adjusted Net Income is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for net income as an indicator of financial performance. The GAAP measure most directly comparable to Adjusted Net Income is net income (loss).
The following table presents a reconciliation of Adjusted Net Income (non-GAAP) to net income (loss), the most directly comparable financial measure calculated in accordance with GAAP:
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| (in thousands) | |||||||||||||||||||||||
| Net income (loss) | $ | (591) | $ | (10,269) | $ | 73,937 | $ | 158,143 | |||||||||||||||
| Unrealized (gain) loss on derivatives | 244,973 | (33,859) | 426,512 | (132,221) | |||||||||||||||||||
| Non-cash equity-based compensation expense | 20,773 | 23,788 | 65,482 | 143,281 | |||||||||||||||||||
| (Gain) loss on sale of assets | (6,065) | 1,641 | (16,755) | (11,131) | |||||||||||||||||||
| Certain RNCI Distributions made by OpCo | — | (605) | — | (5,107) | |||||||||||||||||||
| Transaction and nonrecurring expenses | 40,133 | 19,938 | 86,774 | 29,844 | |||||||||||||||||||
| Settlement of acquired derivative contracts | 33,700 | 14,685 | 156,332 | 49,580 | |||||||||||||||||||
| Impairment expense | — | 73,527 | — | 122,159 | |||||||||||||||||||
| Loss from extinguishment of debt | 16 | 29,248 | 17,413 | 29,248 | |||||||||||||||||||
GAAP Income Tax Expense (Benefit) | 5,984 | (4,031) | 93,631 | 39,638 | |||||||||||||||||||
Provision for Income Taxes on Adjusted Earnings(8) | (84,876) | (22,927) | (210,780) | (83,443) | |||||||||||||||||||
| Adjusted Net Income (non-GAAP) | $ | 254,047 | $ | 91,136 | $ | 692,546 | $ | 339,991 | |||||||||||||||
Adjusted EPS | $ | 0.77 | $ | 0.36 | $ | 2.03 | $ | 1.32 | |||||||||||||||
13
Net Leverage
Crescent defines Net Leverage as the ratio of consolidated total debt to consolidated Adjusted EBITDAX as calculated under the credit agreements (collectively, the “Credit Agreements”) governing the Revolving Credit Facility and CRF Credit Facility, as applicable. Management believes Net Leverage is a useful measurement because it takes into account the impact of acquisitions. For purposes of the Credit Agreements, (i) consolidated total debt is calculated as total principal amount of Senior Notes, net of unamortized discount, premium and issuance costs, plus borrowings on our Revolving Credit Facility or CRF Credit Facility, as applicable, and unreimbursed drawings under letters of credit, less cash and cash equivalents and (ii) consolidated Adjusted EBITDAX includes certain adjustments to account for EBITDAX contributions associated with acquisitions the Company has closed within the last twelve months. Adjusted EBITDAX is a non-GAAP financial measure.
| September 30, 2026 | |||||||||||||||||
Total consolidated | Working interest (CEF) | Minerals and royalties (CRF)(11) | |||||||||||||||
| (in millions) | |||||||||||||||||
Total debt(9)(10) | $ | 4,718 | $ | 3,964 | $ | 82 | |||||||||||
Less: cash and cash equivalents | (6) | (5) | (1) | ||||||||||||||
| Net Debt | $ | 4,712 | $ | 3,959 | $ | 81 | |||||||||||
| Adjusted EBITDAX for Leverage Ratio | $ | 3,100 | $ | 2,913 | $ | 187 | |||||||||||
| Net Leverage | 1.5x | 1.4x | 0.4x | ||||||||||||||
Additional Non-GAAP Measures
Adjusted Recurring Cash G&A
Crescent defines Adjusted Recurring Cash G&A as general and administrative expense, excluding equity-based compensation and transaction and nonrecurring expenses, and including cash distributions initiated by Manager Compensation. We included “Certain RNCI distributions made by OpCo” to reflect Manager Compensation as if 100% of OpCo were owned and managed by the Company, to reflect consistent earnings and liquidity measures not impacted by the amount of OpCo’s ownership under management. Management believes Adjusted Recurring Cash G&A is a useful performance measure because it excludes transaction and nonrecurring expenses and equity-based compensation and includes Manager Compensation as if 100% of OpCo were owned and managed by the Company to reflect consistent measures not impacted by the amount of OpCo’s ownership under management, facilitating the ability for investors to compare Crescent’s cash G&A expense against peer companies. After giving effect to the Corporate Simplification, the Company owns 100% of outstanding OpCo Units and no longer makes distributions to the holders of redeemable noncontrolling interests in OpCo. As discussed elsewhere, these adjustments are made to Adjusted EBITDAX and Levered Free Cash Flow for historical periods.
14
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| (in thousands) | |||||||||||||||||||||||
| General and administrative expense | $ | 65,275 | $ | 74,275 | $ | 189,569 | $ | 255,657 | |||||||||||||||
| Less: Non-cash equity-based compensation expense | (20,773) | (23,788) | (65,482) | (143,281) | |||||||||||||||||||
Less: transaction and nonrecurring expenses (G&A)(12) | (4,708) | (19,643) | (14,003) | (23,732) | |||||||||||||||||||
| Plus: Certain RNCI Distributions made by OpCo | — | — | — | 4,242 | |||||||||||||||||||
| Adjusted Recurring Cash G&A | $ | 39,794 | $ | 30,844 | $ | 110,084 | $ | 92,886 | |||||||||||||||
Adjusted Dividends Paid
Crescent defines Adjusted Dividends Paid as Dividend to Class A Common Stock plus Cash RNCI Distributions initiated by Class A common stock dividend. Management believes Adjusted Dividends Paid is a useful performance measure because it reflects the full amount of cash distributed for dividends that is otherwise classified as distributions to redeemable noncontrolling interests, facilitating the ability for investors to compare Crescent’s dividends paid against peer companies.
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| (in thousands) | |||||||||||||||||||||||
| Dividend to Class A common stock | $ | 39,649 | $ | 30,554 | $ | 118,627 | $ | 84,565 | |||||||||||||||
| Plus: Cash RNCI Distributions initiated by Class A common stock dividend | — | — | — | 7,560 | |||||||||||||||||||
| Adjusted Dividends Paid | $ | 39,649 | $ | 30,554 | $ | 118,627 | $ | 92,125 | |||||||||||||||
(1)Non-GAAP financial measure. Please see “Reconciliation of Non-GAAP Measures” above for discussion and reconciliations of such measures to their most directly comparable financial measures calculated and presented in accordance with GAAP.
(2)Represents 5-year PV-10 of synergies captured to date.
(3)Net purchase price is defined as headline purchase price less estimated purchase price adjustments, including, among other things, allocations of certain revenues and expenses based on a July 1, 2026, effective date, and excludes transaction costs.
(4)The realized price presented above does not include $33.7 million, $14.7 million and $62.1 million received from the settlement of acquired oil, gas and NGL derivative contracts for the three months ended September 30, 2026, September 30, 2025, and June 30, 2026, respectively. Total average realized prices, after effects of derivatives settlements, would have been $40.95, $37.44 and $40.56/Boe for the three months ended September 30, 2026, September 30, 2025, and June 30, 2026, respectively.
(5)Adjusted operating expense, excluding production and other taxes includes lease and asset operating expense, workover expense, gathering, processing and transportation and midstream and other revenue net of expense.
(6)Transaction and nonrecurring expenses of $40.1 million and $86.8 million for the three and nine months ended September 30, 2026, were primarily related to earnout payments in connection with the Company’s acquisition of certain Eagle Ford assets in January 2025 (the “January 2025 Eagle Ford Acquisition”), the Permian Acquisition transaction costs, capital markets transactions, legal settlements, and divestitures and restructuring costs. Transaction and nonrecurring expenses of $19.9 million and $29.8 million for the three and nine months ended September 30, 2025, were primarily related to the Permian Acquisition transaction costs, the January 2025 Eagle Ford Acquisition costs, transaction costs related to our divestitures and the Company’s acquisition of certain Eagle Ford assets in July 2024 (the “July 2024 Eagle Ford Acquisition”) and legal settlement costs.
(7)Represents the settlement of certain oil, gas and NGL commodity derivative contracts acquired in connection with the July 2024 Eagle Ford Acquisition and the Permian Acquisition.
(8)Income taxes on Adjusted Net Income (non-GAAP) represent the amount of income tax expense we would have incurred after giving effect to the items impacting Adjusted Net Income. This tax provision is presented as a separate line item in the calculation of Adjusted Net Income to align the tax expense with the period’s adjusted earnings measure.
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(9)Includes $57.6 million, $38.1 million and $1.5 million of unamortized discount, premium and issuance costs for total consolidated, CEF and CRF, respectively.
(10)Total consolidated debt includes CEF, CRF and corporate-level items (including the 2.75% convertible notes due 2031) and does not equal the sum of CEF and CRF.
(11)During the initial covenant periods until December 31, 2026, Net Leverage for CRF Credit Facility is calculated on an annualized basis.
(12)Transaction and nonrecurring expenses (G&A) of $4.7 million and $14.0 million for the three and nine months ended September 30, 2026, were primarily related to the Permian Acquisition transaction costs, capital markets transactions, legal settlements and divestitures and restructuring costs. Transaction and nonrecurring expenses of $19.6 million and $23.7 million for the three and nine months ended September 30, 2025, were primarily related to the Permian Acquisition transaction costs, the January 2025 Eagle Ford Acquisition costs, transaction costs related to our divestitures and the July 2024 Eagle Ford Acquisition and legal settlement costs.
Company Contact
For additional information, please reach out to IR@crescentenergyco.com.
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