Coterra Energy Inc.
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Financial statements
data from SEC XBRL filings. Values are as-reported; restatements supersede originals. Values reported in .
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ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following review of operations of Coterra Energy Inc. (“Coterra,” the “Company,” “our,” “we” and “us”) for the three month periods ended March 31, 2026 and 2025 should be read in conjunction with our Condensed Consolidated Financial Statements and the Notes included in this Quarterly Report on Form 10-Q (this “Form 10-Q”) and with the Consolidated Financial Statements, Notes and Management’s Discussion and Analysis included in our Annual Report on Form 10-K for the year ended December 31, 2025 filed on February 27, 2026 (our “Form 10-K”).
For the abbreviations and definitions of certain terms commonly used in the oil and gas industry, please see the “Glossary of Certain Oil and Gas Terms” included within our Form 10-K.
OVERVIEW
Pending Merger
On February 1, 2026, we entered into an Agreement and Plan of Merger (the “Merger Agreement”) with Devon Energy Corporation (“Devon”) to combine via an all-stock merger transaction (“Merger”). Devon is a leading oil and gas producer in the U.S. with a diversified multi-basin portfolio headlined by a world-class acreage position in the Delaware Basin. Under terms of the Merger Agreement, at closing our stockholders will receive a fixed exchange ratio of 0.70 shares of Devon common stock for each share of our common stock. Upon completion, Devon stockholders will own approximately 54 percent of the combined company and our stockholders will own approximately 46 percent on a fully diluted basis. The respective Board of Directors of Coterra and Devon unanimously approved the Merger. The Merger Agreement contains customary pre-closing covenants, including the obligation of each of Coterra and Devon to conduct their respective businesses in the ordinary course consistent with past practice and to refrain from taking certain specified actions without the consent of the other party. Until closing, we must continue to operate as a stand-alone company.
On May 4, 2026, our stockholders and Devon stockholders approved the Merger, which is expected to close on May 7, 2026, subject to customary closing conditions.
Financial and Operating Overview
Financial and operating results for the three months ended March 31, 2026 compared to the three months ended March 31, 2025 reflect the following:
•Net income decreased $50 million from $516 million, or $0.68 per share, in 2025 to $466 million, or $0.61 per share, in 2026.
•Net cash provided by operating activities increased $502 million, from $1.1 billion in 2025 to $1.6 billion in 2026.
•Equivalent production increased 2.2 MMBoe from 67.2 MMBoe, or 746.8 MBoe per day, in 2025 to 69.4 MMBoe, or 771.0 MBoe per day, in 2026.
◦Oil production increased 2.0 MMBbl from 12.7 MMBbl, or 141.2 MBbl per day, in 2025 to 14.7 MMBbl, or 163.7 MBbl per day, in 2026.
◦Natural gas production decreased 16.0 Bcf from 273.9 Bcf, or 3,043.8 MMcf per day, in 2025 to 257.9 Bcf, or 2,866.0 MMcf per day, in 2026.
◦NGL volumes increased 2.9 MMBbl from 8.8 MMBbl, or 98.3 MBbl per day, in 2025 to 11.7 MMBbl, or 129.7 MBbl per day, in 2026.
•Average realized prices (including impact of derivatives):
◦Oil was $67.28 per Bbl in 2026, 3 percent lower than the $69.30 per Bbl realized in 2025.
◦Natural gas was $4.10 per Mcf in 2026, 28 percent higher than the $3.21 per Mcf realized in 2025.
◦NGL price was $16.70 per Bbl in 2026, 28 percent lower than the $23.23 per Bbl realized in 2025.
•Total capital expenditures for drilling, completion and other fixed assets were $655 million in 2026 compared to $552 million in the corresponding period of the prior year.
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Other financial highlights for the three months ended March 31, 2026 include the following:
•Announced our quarterly dividend of $0.22 per share in February 2026.
•Repaid the remaining $300 million outstanding under the Term Loan.
•Repurchased and retired 1 million shares of our common stock for $32 million.
Market Conditions and Commodity Prices
Our financial results depend on many factors, particularly commodity prices and our ability to find and develop oil and gas reserves and market our production on economically attractive terms. Commodity prices are affected by many factors outside of our control, including changes in market supply and demand, which can be impacted by pipeline capacity constraints, inventory storage levels, basis differentials, weather conditions, and geopolitical, economic and other factors.
While oil prices declined overall in 2025, spot and future prices have surged in 2026 due to acute geopolitical disruption. Forecasts for growing global oil demand follow a modest trend based upon economic conditions and are subject to volatile market conditions, including ongoing shifts in U.S. and international trade policy, as well as geopolitical risk and uncertainty. These geopolitical risks and uncertainties include, among other items, the U.S.-Iran conflict that began in late February 2026 and the impacts thereof on traffic through the Strait of Hormuz and Persian Gulf producers. While spot and future prices have traded with increased volatility since the outbreak of the conflict, the longer-term impacts of these changes remain to be seen, including the effects on domestic U.S. oil production and capital expenditure for the same.
Natural gas prices rose overall in 2025 and are forecasted to strengthen further into 2026, driven by shifting weather models and expected growing LNG exports. Additionally, increasing power generation opportunities for natural gas, both from demands for electric grids fueled by natural gas-power generation and off-grid demand related to datacenter growth, is anticipated to buoy natural gas prices. Basis differentials have continued to persist in the U.S., with prices at the Waha Hub in the Permian Basin reaching negative spot pricing throughout early 2026 due to oversupply and maintenance, however we expect that additional pipeline capacity coming online beginning in late 2026 will alleviate the spread on Waha basis differentials for natural gas. We continue to expect natural gas prices overall to be stronger in 2026 compared to 2025.
Although the current outlook on oil and natural gas prices is generally favorable, and our operations have not been significantly impacted in the short-term, in the event further disruptions occur or the current market volatility and U.S. and international economic policy uncertainty continues for an extended period of time, our operations could be adversely impacted, commodity prices could decline and our costs may increase. We expect commodity price volatility to continue, including as a result of U.S. and international economic policy (such as tariffs or retaliatory tariffs), actions of OPEC+ (including the ability of OPEC+ to successfully coordinate production quotas and the exit of members from OPEC+) and potentially swift near- and medium-term fluctuations in supply and demand, such as potential changes to drilling and capital programs in the short term by U.S. producers. While we are unable to predict future commodity prices, at current oil, natural gas and NGL price levels, we do not believe that an impairment of our oil and gas properties is reasonably likely to occur in the near future. However, in the event that commodity prices significantly decline or costs significantly increase from current levels, our management would evaluate the recoverability of the carrying value of our oil and gas properties.
For information about the impact of realized commodity prices on our revenues, refer to “Results of Operations” below.
Outlook
Our first quarter 2026 total production volumes exceeded our internal expectations. During the quarter, Winter Storm Fern adversely impacted operations, resulting in curtailed oil production of approximately 3.0 MBbl per day and 6.5 MBoe per day. Consistent with our internal expectations, 2026 capital expenditures are expected to be weighted to the first half of 2026.
We are reiterating the full-year 2026 guidance ranges previously announced in February. These guidance ranges reflect Coterra on a standalone basis, including with respect to capital expenditures, production and operating expense, and do not give effect to the planned merger with Devon.
FINANCIAL CONDITION
Liquidity and Capital Resources
We strive to maintain an adequate liquidity level to address commodity price volatility and risk. Our liquidity requirements consist primarily of our planned capital expenditures, payment of contractual obligations (including debt maturities and interest payments), working capital requirements, dividend payments and share repurchases. Although we have
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no obligation to do so, we may also from time-to-time refinance or retire our outstanding debt through privately negotiated transactions, open market repurchases, redemptions, exchanges, tender offers or otherwise.
Our primary sources of liquidity are cash on hand, net cash provided by operating activities and available borrowing capacity under our revolving credit agreement. Our liquidity requirements are generally funded with cash flows provided by operating activities, together with cash on hand and draws under our revolving credit agreement. However, from time-to-time, our investments may be funded by sales of assets and private or public financing based on our monitoring of capital markets and our balance sheet. While there are no “rating triggers” in any of our debt agreements that would accelerate the scheduled maturities should our credit rating fall below a certain level, a change in our credit rating could adversely impact our interest rate on any borrowings under our revolving credit agreement and our ability to economically access debt markets and could trigger the requirement to post credit support under various agreements, which could reduce the borrowing capacity under our revolving credit agreement. As of the date hereof, our debt is currently rated as investment grade by the three leading ratings agencies. For more on the impact of credit ratings on our interest rates and fees for unused commitments under our revolving credit agreement, see Note 4 of the Notes to the Consolidated Financial Statements in our Form 10-K. We believe that, with operating cash flow, cash on hand and availability under our revolving credit agreement, we have the ability to finance our spending plans over the next 12 months and, based on current expectations, for the longer term.
Our working capital is substantially influenced by the variables discussed above and fluctuates based on the timing and amount of borrowings and repayments under our revolving credit agreement, borrowings and repayments of debt, the timing of cash collections and payments on our trade accounts receivable and payable, respectively, payment of dividends, repurchases of our securities and changes in the fair value of our commodity derivative activity. From time-to-time, our working capital will reflect a deficit, while at other times it will reflect a surplus. This fluctuation is not unusual. As of March 31, 2026, our working capital surplus of $10 million was lower than at December 31, 2025, primarily due to higher accounts payable and accrued liabilities, partially offset by higher cash and cash equivalents. As of December 31, 2025, we had a working capital surplus of $292 million. We believe we have adequate liquidity and availability under our revolving credit agreement as outlined above to meet our working capital requirements and debt repayments over the next 12 months.
As of March 31, 2026, we had unrestricted cash on hand of $485 million and unused commitments of $2.0 billion under our revolving credit agreement.
Our revolving credit agreement includes a covenant potentially limiting our borrowing capacity as determined by our leverage ratio. As of March 31, 2026, we were in compliance with all financial covenants applicable to our revolving credit agreement and private placement senior notes. Refer to Note 4 of the Notes to the Condensed Consolidated Financial Statements in this report and Note 4 of the Notes to the Consolidated Financial Statements in our Form 10-K for further details.
Cash Flows
Our cash flows from operating activities, investing activities and financing activities were as follows:
| Three Months Ended March 31, | Variance | |||||||||||||||||||||||
| (In millions) | 2026 | 2025 | Amount | Percent | ||||||||||||||||||||
| Cash flows provided by operating activities | $ | 1,646 | $ | 1,144 | $ | 502 | 44 | % | ||||||||||||||||
| Cash flows used in investing activities | (756) | (3,728) | 2,972 | (80) | % | |||||||||||||||||||
| Cash flows (used in) provided by financing activities | (519) | 528 | (1,047) | (198) | % | |||||||||||||||||||
| Net increase (decrease) in cash, cash equivalents and restricted cash | $ | 371 | $ | (2,056) | $ | 2,427 | (118) | % | ||||||||||||||||
Operating Activities. Operating cash flow fluctuations are substantially driven by changes in commodity prices, production volumes and operating expenses. As discussed above, commodity prices have historically been volatile. Fluctuations in cash flow may result in an increase or decrease in our planned capital expenditures.
Net cash provided by operating activities for the three months ended March 31, 2026 increased by $502 million compared to the same period in 2025. This increase was primarily due to higher oil and natural gas revenues driven by higher oil and natural gas prices and higher oil production. These increases were partially offset by an increase in operating costs during the first three months of 2026 compared to 2025.
Refer to “Results of Operations” below for additional information relative to commodity prices, production and operating expense fluctuations. We are unable to predict future commodity prices and, as a result, cannot provide any assurance about future levels of net cash provided by operating activities.
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Investing Activities. Cash flows used in investing activities decreased by $3.0 billion for the three months ended March 31, 2026 compared to the same period in 2025. This decrease was primarily due to $3.2 billion of net cash consideration paid for the FME and Avant acquisitions that closed in January 2025, partially offset by $161 million higher cash paid for capital expenditures in 2026 compared to 2025.
Financing Activities. Cash flows used in financing activities increased by $1.0 billion for the three months ended March 31, 2026 compared to the same period in 2025 primarily due to lower proceeds from debt issuances and higher repayments of debt. In 2025, we received $1.0 billion proceeds under our term loans to fund the FME and Avant acquisitions that closed in January 2025, compared to $169 million of proceeds from our revolving credit facility in 2026. Additionally, we repaid the remaining $300 million balance under the term loan and $169 million of borrowings under our revolving credit facility in 2026 compared to the repayment of $250 million of debt in 2025.
Capitalization
Information about our capitalization is as follows:
| (Dollars in millions) | March 31, 2026 | December 31, 2025 | ||||||||||
Total debt (1) | $ | 3,513 | $ | 3,818 | ||||||||
Stockholders’ equity | 15,106 | 14,838 | ||||||||||
| Total capitalization | $ | 18,619 | $ | 18,656 | ||||||||
| Debt to total capitalization | 19 | % | 20 | % | ||||||||
| Cash and cash equivalents | $ | 485 | $ | 114 | ||||||||
________________________________________________________
(1) There were no borrowings outstanding under our revolving credit agreement as of March 31, 2026 and December 31, 2025.
Share repurchases. During the three months ended March 31, 2026, we repurchased and retired 1 million shares of our common stock for $32 million. We repurchased and retired 1 million shares of our common stock for $24 million during the three months ended March 31, 2025.
As of March 31, 2026, we had $1.0 billion remaining under our current share repurchase program.
Dividends. In February 2026, our Board of Directors approved a quarterly dividend of $0.22 per share.
The following table summarizes our dividends on our common stock for the three months ended March 31, 2026 and 2025:
| Rate Per Share | Total Dividends (In millions) | |||||||||||||||||||
| 2026 | ||||||||||||||||||||
| First quarter | $ | 0.22 | $ | 167 | ||||||||||||||||
| $ | 0.22 | $ | 167 | |||||||||||||||||
| 2025 | ||||||||||||||||||||
| First quarter | $ | 0.22 | $ | 170 | ||||||||||||||||
| $ | 0.22 | $ | 170 | |||||||||||||||||
Capital and Exploration Expenditures
On an annual basis, we generally fund most of our capital expenditures, excluding any significant property acquisitions, with cash flow provided by operating activities, and, if required, borrowings under our revolving credit agreement. We budget these expenditures based on our projected cash flows for the year.
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The following table presents major components of our capital and exploration expenditures:
| Three Months Ended March 31, | |||||||||||||
| (In millions) | 2026 | 2025 | |||||||||||
| Acquisitions | |||||||||||||
| Proved oil and gas properties | $ | — | $ | 2,510 | |||||||||
| Unproved oil and gas properties | — | 1,253 | |||||||||||
| Gathering and pipeline systems | — | 333 | |||||||||||
| $ | — | $ | 4,096 | ||||||||||
| Capital expenditures: | |||||||||||||
| Drilling and facilities | $ | 613 | $ | 512 | |||||||||
| Pipeline and gathering | 30 | 29 | |||||||||||
| Other | 12 | 11 | |||||||||||
| Capital expenditures for drilling, completion and other fixed asset additions | 655 | 552 | |||||||||||
| Capital expenditures for leasehold and property acquisitions | 15 | 37 | |||||||||||
Exploration expenditures (1) | 5 | 10 | |||||||||||
| $ | 675 | $ | 599 | ||||||||||
________________________________________________________
(1)There were no exploratory dry hole costs for the three months ended March 31, 2026 and 2025.
For the three months ended March 31, 2026, our capital program focused on the Permian Basin, Marcellus Shale and Anadarko Basin, where we drilled 47.6 net wells and turned-in-line 51.4 net wells.
Contractual Obligations
We have various contractual obligations in the normal course of our operations. There have been no material changes to our contractual obligations described under “Gathering, Processing and Transportation Agreements,” “Power Purchase Commitments” and “Lease Commitments” as disclosed in Note 8 of the Notes to the Consolidated Financial Statements and the obligations described under “Contractual Obligations” in Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in our Form 10-K.
Critical Accounting Policies and Estimates
Our discussion and analysis of our financial condition and results of operations are based on our Condensed Consolidated Financial Statements, which have been prepared in accordance with GAAP. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. Refer to our Form 10-K for further discussion of our critical accounting policies.
RESULTS OF OPERATIONS
First Three Months of 2026 and 2025 Compared
Operating Revenues
| Three Months Ended March 31, | Variance | |||||||||||||||||||||||
| (In millions) | 2026 | 2025 | Amount | Percent | ||||||||||||||||||||
| Oil | $ | 1,043 | $ | 886 | $ | 157 | 18 | % | ||||||||||||||||
| Natural gas | 1,110 | 898 | 212 | 24 | % | |||||||||||||||||||
| NGL | 195 | 206 | (11) | (5) | % | |||||||||||||||||||
| Loss on derivative instruments, net | (434) | (112) | (322) | 288 | % | |||||||||||||||||||
| Other | 33 | 26 | 7 | 27 | % | |||||||||||||||||||
| $ | 1,947 | $ | 1,904 | $ | 43 | 2 | % | |||||||||||||||||
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Production Revenues
Our production revenues are derived from sales of our oil, natural gas and NGL production. Increases or decreases in our revenues, profitability and future production growth are highly dependent on the commodity prices we receive, which, as discussed above, fluctuate due to a variety of factors, including supply and demand, the availability of transportation, seasonality and geopolitical, economic and other factors.
Production and Sales Price
The following table presents our total and average daily production volumes for oil, natural gas and NGLs, and our average oil, natural gas and NGL sales prices for the periods indicated.
| Three Months Ended March 31, | Variance | |||||||||||||||||||||||
| 2026 | 2025 | Amount | Percent | |||||||||||||||||||||
| Production Volumes | ||||||||||||||||||||||||
| Oil (MMBbl) | 14.7 | 12.7 | 2.0 | 16 | % | |||||||||||||||||||
| Natural gas (Bcf) | 257.9 | 273.9 | (16.0) | (6) | % | |||||||||||||||||||
| NGL (MMBbl) | 11.7 | 8.8 | 2.9 | 32 | % | |||||||||||||||||||
Equivalents (MMBoe) | 69.4 | 67.2 | 2.2 | 3 | % | |||||||||||||||||||
| Average Daily Production Volumes | ||||||||||||||||||||||||
| Oil (MBbl) | 163.7 | 141.2 | 22.5 | 16 | % | |||||||||||||||||||
| Natural gas (MMcf) | 2,866.0 | 3,043.8 | (177.8) | (6) | % | |||||||||||||||||||
| NGL (MBbl) | 129.7 | 98.3 | 31.4 | 32 | % | |||||||||||||||||||
Equivalents (MBoe) | 771.0 | 746.8 | 24.2 | 3 | % | |||||||||||||||||||
| Average Sales Price | ||||||||||||||||||||||||
| Excluding Derivative Settlements | ||||||||||||||||||||||||
| Oil ($/Bbl) | $ | 70.79 | $ | 69.73 | $ | 1.06 | 2 | % | ||||||||||||||||
| Natural gas ($/Mcf) | $ | 4.30 | $ | 3.28 | $ | 1.02 | 31 | % | ||||||||||||||||
| NGL ($/Bbl) | $ | 16.70 | $ | 23.23 | $ | (6.53) | (28) | % | ||||||||||||||||
| Including Derivative Settlements | ||||||||||||||||||||||||
| Oil ($/Bbl) | $ | 67.28 | $ | 69.30 | $ | (2.02) | (3) | % | ||||||||||||||||
| Natural gas ($/Mcf) | $ | 4.10 | $ | 3.21 | $ | 0.89 | 28 | % | ||||||||||||||||
| NGL ($/Bbl) | $ | 16.70 | $ | 23.23 | $ | (6.53) | (28) | % | ||||||||||||||||
Oil Revenues
| Three Months Ended March 31, | Variance | Increase (Decrease) (In millions) | |||||||||||||||||||||||||||
| 2026 | 2025 | Amount | Percent | ||||||||||||||||||||||||||
Volume (MMBbl) | 14.7 | 12.7 | 2.0 | 16 | % | $ | 141 | ||||||||||||||||||||||
Price ($/Bbl) | $ | 70.79 | $ | 69.73 | $ | 1.06 | 2 | % | 16 | ||||||||||||||||||||
| $ | 157 | ||||||||||||||||||||||||||||
Oil revenues increased $157 million primarily due to higher production in the Permian Basin and slightly higher oil prices.
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Natural Gas Revenues
| Three Months Ended March 31, | Variance | Increase (Decrease) (In millions) | |||||||||||||||||||||||||||
| 2026 | 2025 | Amount | Percent | ||||||||||||||||||||||||||
Volume (Bcf) | 257.9 | 273.9 | (16.0) | (6) | % | $ | (52) | ||||||||||||||||||||||
Price ($/Mcf) | $ | 4.30 | $ | 3.28 | $ | 1.02 | 31 | % | 264 | ||||||||||||||||||||
| $ | 212 | ||||||||||||||||||||||||||||
Natural gas revenues increased $212 million primarily due to higher natural gas prices and higher production in the Permian and Anadarko Basins, partially offset by lower production in the Marcellus Shale.
NGL Revenues
| Three Months Ended March 31, | Variance | Increase (Decrease) (In millions) | |||||||||||||||||||||||||||
| 2026 | 2025 | Amount | Percent | ||||||||||||||||||||||||||
Volume (MMBbl) | 11.7 | 8.8 | 2.9 | 32 | % | $ | 66 | ||||||||||||||||||||||
Price ($/Bbl) | $ | 16.70 | $ | 23.23 | $ | (6.53) | (28) | % | (77) | ||||||||||||||||||||
| $ | (11) | ||||||||||||||||||||||||||||
NGL revenues decreased $11 million primarily due to lower NGL prices partially offset by higher volumes in the Permian and Anadarko Basins.
Loss on Derivative Instruments, Net
Net gains and losses on our derivative instruments are a function of fluctuations in the underlying commodity index prices as compared to the contracted prices and the monthly cash settlements (if any) of the derivative instruments. We have elected not to designate our derivatives as hedging instruments for accounting purposes and, therefore, we do not apply hedge accounting treatment to our derivative instruments. Consequently, changes in the fair value of our derivative instruments and cash settlements are included as a component of operating revenues as either a net gain or loss on derivative instruments. Cash settlements of our contracts are included in cash flows from operating activities in our statement of cash flows.
The following table presents the components of “Loss on derivative instruments, net” for the periods indicated:
| Three Months Ended March 31, | |||||||||||||||||||||
| (In millions) | 2026 | 2025 | |||||||||||||||||||
Cash paid on settlement of derivative instruments | |||||||||||||||||||||
| Oil contracts | $ | (52) | $ | (5) | |||||||||||||||||
| Gas contracts | (53) | (17) | |||||||||||||||||||
| Non-cash gain (loss) on derivative instruments | |||||||||||||||||||||
| Oil contracts | (410) | 5 | |||||||||||||||||||
| Gas contracts | 81 | (95) | |||||||||||||||||||
| $ | (434) | $ | (112) | ||||||||||||||||||
Operating Costs and Expenses
Costs associated with producing oil and natural gas are substantial. Among other factors, some of these costs vary with commodity prices, some trend with the volume and commodity mix, some are a function of the number of wells we own and operate, some depend on the prices charged by service companies, and some fluctuate based on a combination of the foregoing. Our costs for services, labor and supplies have modestly declined driven by lower industry activity levels and current oil prices. These savings are being partially offset by tariff impacts that many vendors have faced. In January 2025 with the completion of the FME and Avant acquisitions, we expanded our operations in the Permian Basin.
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The table below reflects our operating costs and expenses for the periods indicated, and a discussion of the operating costs and expenses follows:
Next expected filings
- ~2026-11-07 10-Q expected by 2026-11-12 (in 74 days)
- ~2027-03-01 10-K expected by 2027-03-04 (in 188 days)
- ~2027-05-09 10-Q expected by 2027-05-14 (in 257 days)
- ~2027-08-08 10-Q expected by 2027-08-13 (in 348 days)
Predicted from historical filing cadence; not an SEC commitment.
Recent SEC filings
- 2026-05-07 8-K Material Agreement Terminated; Completion of Acquisition/Disposition; Delisting Notice; Material Modification to Rights; Control Change; Officer/Director Change; Financial Statements and Exhibits
- 2026-05-06 10-Q Quarterly Report
- 2026-04-24 10-K/A Annual Report (Amended)
- 2026-04-24 8-K Other Events
- 2026-04-02 8-K Other Events
- 2026-02-27 10-K Annual Report
- 2026-02-26 8-K Earnings Release; Other Events; Financial Statements and Exhibits
- 2026-02-02 8-K Material Agreement Entered; Officer/Director Change; Regulation FD Disclosure; Other Events; Financial Statements and Exhibits
- 2026-01-21 8-K Earnings Release; Financial Statements and Exhibits
- 2025-11-04 10-Q Quarterly Report
- 2025-11-03 8-K Earnings Release; Financial Statements and Exhibits
- 2025-10-22 8-K Earnings Release; Financial Statements and Exhibits
- 2025-09-22 8-K Officer/Director Change; Financial Statements and Exhibits
- 2025-08-05 10-Q Quarterly Report
- 2025-08-04 8-K Earnings Release; Financial Statements and Exhibits