The Company’s full year 2025 results reflect the closing of its transformative merger with certain portfolio companies controlled by
Select Financial & Operational Data
Fourth Quarter 2025
| ($000s except as noted) | Q4 2025 | Q4 2024 | Change | ||||
| Average Daily Production (Boe/d) | 5,310 | 2,181 | +143% | ||||
| Revenue | +118% | ||||||
| Net (Loss) Income | (8,501 | ) | -243% | ||||
| Adjusted EBITDA(1) | +203% | ||||||
Full-Year 2025
| ($000s except as noted) | FY 2025 | FY 2024 | Change | ||||
| Average Daily Production (Boe/d) | 2,494 | 1,835 | +36% | ||||
| Revenue | +16% | ||||||
| Net (Loss) Income | $(10,362 | ) | -184% | ||||
| Adjusted EBITDA(1) | +18% | ||||||
(1) Adjusted EBITDA is a non-GAAP financial measure. See “Use of Non-GAAP Financial Information” and the reconciliation table at the end of this release.
Note: Fourth quarter 2025 figures are derived from audited full year 2025 results and unaudited nine-month results as reported in the Company’s Quarterly Report on Form 10-Q for the period ended
Fourth Quarter Financial and Operational Highlights Include:
- Fourth quarter 2025 production of 483,159 Boe (Average 5,310 Boe/d), a 143% increase over fourth quarter 2024 production. The acquired assets contributed approximately 303,000 Boe during November and
December 2025 . - Fourth quarter 2025 oil and gas revenue of approximately
$23.1 million , more than doubling the$10.6 million reported in the fourth quarter of 2024, reflecting the initial contribution from the acquired Juniper assets. - Fourth quarter 2025 Adjusted EBITDA(1) of approximately
$15.4 million , compared to$5.1 million in the fourth quarter of 2024, representing a nearly threefold increase.
Full Year Financial and Operational Highlights Include:
- Full year 2025 production of 910,068 Boe (2,494 Average Boe/d), a 35% increase over 2024 production of 671,796 Boe (1,835 Average Boe/d), supported by the contribution of the acquired assets during the last two months of the year.
- Full year 2025 oil and gas revenue of
$45.8 million , a 16% increase over full year 2024 revenue of$39.6 million , driven by a 35% increase in sale volumes partially offset by a 19% decline in average realized crude oil prices. - Full year 2025 Adjusted EBITDA(1) of
$27.0 million , an 18% increase over full year 2024 Adjusted EBITDA of$22.9 million , reflecting the contribution of two months of production from the acquired assets and continued execution of the Company’s development program. - Full year 2025 net loss of
$(10.4) million , or$(2.25) per diluted share, compared to net income of$12.3 million (restated), or$2.76 per diluted share, in 2024. The year-over-year decline was driven primarily by approximately$7.5 million of non-recurring merger-related costs,$2.8 million in additional and accelerated share-based compensation in connection with board transitions related to the Juniper Merger,$1.4 million of new interest expense on the Company’s credit facility, a$1.4 million note receivable write-off and an income tax expense of$8.1 million , resulting in a net deferred tax liability of$0.8 million on the Company’s consolidated balance sheet. - Year-end 2025 total proved reserves of 32.1 MMBoe with PV-10(2) of
$357.7 million , compared to 18.1 MMBoe and$178.9 million , respectively, at year-end 2024, reflecting the full post-merger asset base. - Year-end 2025 revolving credit facility balance of
$87.0 million under the Company’s Amended and Restated Credit Agreement withCitibank, N.A . ($120 million borrowing base;$250 million maximum facility).
(2) PV-10 is a non-GAAP financial measure. See “Use of Non-GAAP Financial Information” for additional disclosure.
2026 Guidance Highlights:
- Full-year 2026 guidance for net capital expenditures of
$16 million to$20 million , including approximately$6 million to$7 million for drilling and completion costs in the D-J Basin (of which approximately$3 million is carry over from the Company’s 2025 program), and approximately$10 million to$13 million in estimated capital expenditures for optimization projects on our newly acquired assets from the Juniper Merger. Asset reviews of the newly combined entity are currently underway and an expansion of the 2026 capital budget will be announced in the coming months. - Full-year 2026 guidance for adjusted EBITDA of
$60 million to$70 million , based on average oil price of$65 /bbl and average gas price of$3.50 /Mscf
Management Commentary
“2025 was a transformational year for
“Our fourth quarter results, with revenue exceeding
“Looking ahead to 2026, our priorities are clear: continue disciplined development, reduce operating costs through targeted optimization of the acquired asset base, and demonstrate the full earnings power of the combined platform while searching for accretive Rockies acquisitions to further scale the platform. We believe 2025 has positioned
Fourth Quarter Financial Summary
Revenue. Total crude oil, natural gas and NGL revenues for the three-month period ended
Lease Operating Expenses. LOE increased
General and Administrative Expenses. Total G&A expense (including share-based compensation) increased
Depreciation, Depletion, Amortization and Accretion. DD&A increased
Gain on Derivative Contracts. The Company recognized a total gain of
Interest Expense. The Company incurred
Net (Loss) Income. The Company reported net loss of
Adjusted EBITDA. Adjusted EBITDA was
Full Year 2025 Financial Summary
Revenue. Total crude oil, natural gas and NGL revenues for the year ended
Lease Operating Expenses. LOE increased
General and Administrative Expenses. Total G&A expense (including share-based compensation) increased
Depreciation, Depletion, Amortization and Accretion. DD&A increased
Gain on Derivative Contracts. The Company recognized a total gain of
Interest Expense. The Company incurred
Net (Loss) Income. The Company reported a net loss of
Adjusted EBITDA. Adjusted EBITDA was
Production and Realized Price Summary
| Year Ended | Year Ended | % Change | ||||||
| Production Volumes: | ||||||||
| Crude Oil (Bbls) | 672,924 | 492,396 | +37% | |||||
| Natural Gas (Mcf) | 770,919 | 608,382 | +27% | |||||
| NGL (Bbls) | 108,657 | 78,003 | +39% | |||||
| Total (Boe) | 910,068 | 671,796 | +35% | |||||
| Average Daily (Boe/d) | 2,494 | 1,835 | +36% | |||||
| Average Realized Prices: | ||||||||
| Crude Oil ($/Bbl) | (19)% | |||||||
| Natural Gas ($/Mcf) | +73% | |||||||
| NGL ($/Bbl) | (4)% | |||||||
| Per-Unit Economics ($/Boe): | ||||||||
| Average Realized Revenue | (15)% | |||||||
| Lease Operating Expenses(4) | ( | ( | +12% | |||||
| Cash Operating Margin(5) | $38.65 | $48.52 | (20)% | |||||
(4) Per-unit LOE represents direct lease operating expenses per Boe as reported in the Company’s 10-K MD&A and excludes gathering, processing, and transportation (“GP&T”), production taxes, and other operating costs included in total lease operating costs on the income statement.
(5) Cash operating margin per Boe is calculated as average realized revenue per Boe less per-unit LOE. This is a supplemental measure for illustrative purposes; it excludes G&A, DD&
Operational Update
D-
Year-End 2025 Proved Reserves
The Company’s year-end 2025 proved reserves were evaluated by
- Total proved reserves of 32.1 MMBoe (22.99 MMBbl oil, 28.78 Bcf gas, 4.34 MMBbl NGL), an increase of 14.0 MMBoe, or 77%, from year-end 2024
- PV-10 of
$357.7 million , an increase of approximately$178.8 million , or 100%, from year-end 2024 - Proved developed reserves of 16.38 MMBoe (PV-10:
$257.4 million , representing 72% of total PV-10) - Proved undeveloped reserves of 15.74 MMBoe (PV-10:
$100.2 million ), reflecting 71 horizontal drilling locations across the D-J Basin andPermian Basin SEC pricing assumptions:$65.34 per barrel of oil and$3.387 per MMBtu of natural gas- Reserve-to-production ratio of approximately 10+ years at current production levels
Additional details on the Company’s proved reserves are available in the Company’s reserves press release dated
Liquidity, Capital Structure
Balance Sheet. As of
Derivatives. As of
Reverse Stock Split. Effective
Earnings Conference Call
Dial-in registration link: here
Live webcast registration link: here
The conference call will also be available for replay in the Events section of the Company’s website, along with the transcript, at https://www.pedevco.com/investors.
If you have any difficulty registering for or connecting to the conference call, please contact Elevate IR at PED@elevate-ir.com.
About
Cautionary Statement Regarding Forward-Looking Statements
This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Words such as “may,” “could,” “expect,” “intend,” “plan,” “seek,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “continue,” “likely,” “will,” “would” and variations of these terms and similar expressions, or the negative of these terms or similar expressions, are intended to identify forward-looking statements. These statements involve known and unknown risks, uncertainties and other factors, which may cause actual results to differ materially from those expressed or implied. Forward-looking statements in this release include, but are not limited to, statements regarding the Company’s 2026 capital expenditure estimates, expected benefits of the Juniper Merger including cost savings and operational synergies, expected production levels, development plans, estimated reserves, and the Company’s ability to fund its operations and service its obligations. Factors that could cause actual results to differ include, among others: volatility in oil and natural gas prices; the Company’s ability to successfully integrate the acquired operations; the Company’s ability to service its credit facility obligations; results of development and production activities; changes in operating costs; regulatory developments including those affecting federal and state leases; the Company’s ability to maintain its listing on NYSE American; availability and costs of services and materials; and the risks described in the Company’s Annual Report on Form 10-K for the year ended
Use of Non-GAAP Financial Information
This press release includes EBITDA, Adjusted EBITDA, and PV-10, which are presented as supplemental measures of the Company’s performance and asset value. These are not recognized in accordance with generally accepted accounting principles (“GAAP”) and should not be viewed as an alternative to GAAP measures of performance.
EBITDA represents net income before interest, taxes, depreciation and amortization. Adjusted EBITDA represents EBITDA less share-based compensation, impairment of oil and gas properties, gain on sale of oil and gas properties, gain on sale of fixed asset, merger acquisition costs, and note receivable – credit loss. The Company believes these measures provide additional useful information to investors and are frequently used by analysts, investors and other interested parties to evaluate companies in the oil and gas industry. However, EBITDA and Adjusted EBITDA have limitations and should not be considered in isolation or as substitutes for analysis of results as reported under GAAP. Additionally, the Company’s calculation of these measures may differ from similarly titled measures used by other companies. A reconciliation of net income to Adjusted EBITDA is provided at the end of this release.
PV-10 represents the present value of estimated future net revenues from proved reserves, before income taxes, discounted at 10% per annum. PV-10 is not a measure prescribed by GAAP. The most directly comparable GAAP measure is the standardized measure of discounted future net cash flows (“Standardized Measure”), which includes the effects of income taxes. The Company uses PV-10 as a measure of the relative value of its properties because it is a widely used industry metric that is not dependent on the tax position of individual companies. A reconciliation of PV-10 to the Standardized Measure is available in the Company’s Annual Report on Form 10-K for the year ended
CONSOLIDATED BALANCE SHEETS
(amounts in thousands, except share and per share data)
| 2025 | 2024 | |||
| ASSETS | ||||
| Current assets: | ||||
| Cash | ||||
| Accounts receivable – oil and gas | 25,666 | 7,995 | ||
| Note receivable, current | — | 293 | ||
| Inventory | 61 | — | ||
| Derivative contract assets - current | 8,368 | — | ||
| Prepaid expenses and other current assets | 434 | 917 | ||
| Total current assets | 37,751 | 13,215 | ||
| Total oil and gas properties, net | 322,270 | 103,512 | ||
| Note receivable | — | 933 | ||
| Operating lease – right-of-use asset | 213 | 224 | ||
| Derivative contract assets | 9,640 | — | ||
| Deferred income taxes | — | 7,255 | ||
| Other assets | 5,995 | 3,210 | ||
| TOTAL ASSETS | $375,869 | $128,349 | ||
| LIABILITIES AND SHAREHOLDERS’ EQUITY | ||||
| Current liabilities: | ||||
| Accounts payable | ||||
| Accrued expenses | 8,245 | 2,255 | ||
| Revenue payable | 21,480 | 1,266 | ||
| Operating lease liabilities – current | 182 | 99 | ||
| Derivative contract liabilities – current | 964 | — | ||
| Asset retirement obligations – current | 1,170 | 663 | ||
| Total current liabilities | 64,477 | 6,908 | ||
| Revolving credit facility | 87,000 | — | ||
| Operating lease liabilities, net of current | 32 | 129 | ||
| Derivative contract liabilities | 6,358 | — | ||
| Asset retirement obligations, net of current | 7,641 | 5,708 | ||
| Deferred income taxes | 800 | — | ||
| Other long-term liabilities | 2,197 | — | ||
| Total liabilities | 168,505 | 12,745 | ||
| Shareholders’ equity: | ||||
| Series A preferred stock | 17,014 | — | ||
| Common stock | 5 | 4 | ||
| Additional paid-in capital | 312,205 | 227,098 | ||
| Accumulated deficit | (121,860) | (111,498) | ||
| Total shareholders’ equity | 207,364 | 115,604 | ||
| TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY | $375,869 | $128,349 | ||
CONSOLIDATED STATEMENTS OF OPERATIONS
(amounts in thousands, except per share data)
| Year Ended | Year Ended | |||
| Revenue: | ||||
| Oil and gas sales | ||||
| Operating expenses: | ||||
| Lease operating costs | 19,120 | 12,449 | ||
| Selling, general and administrative expense | 16,788 | 6,391 | ||
| Impairment of oil and gas properties | 908 | — | ||
| Depreciation, depletion, amortization and accretion | 18,009 | 15,920 | ||
| Total operating expenses | 54,825 | 34,760 | ||
| Gain (loss) on sale of oil and gas properties, net | 2,597 | (76) | ||
| Note receivable – credit loss | (1,378) | — | ||
| Operating (loss) income | (7,855) | 4,717 | ||
| Other income (expense): | ||||
| Interest expense | (1,407) | — | ||
| Interest income | 274 | 351 | ||
| Gain on sale of fixed asset | — | 12 | ||
| Net gain on derivative contracts | 6,253 | — | ||
| Other income (expense) | 428 | (42) | ||
| Total other income | 5,548 | 321 | ||
| (Loss) income before income taxes | (2,307) | 5,038 | ||
| Income tax (expense) benefit | (8,055) | 7,255 | ||
| Net (loss) income | $(10,362) | $12,293 | ||
| Earnings (loss) per common share: | ||||
| Basic | ||||
| Diluted | ||||
| Weighted average shares outstanding: | ||||
| Basic | 4,615,058 | 4,461,732 | ||
| Diluted | 4,615,058 | 4,461,732 | ||
CONSOLIDATED STATEMENTS OF CASH FLOWS
(amounts in thousands)
| Year Ended | Year Ended | |||
| Operating Activities: | ||||
| Net (loss) income | ||||
| Adjustments: | ||||
| DD&A and accretion | 18,009 | 15,920 | ||
| Impairment of oil and gas properties | 908 | — | ||
| Note receivable – credit loss | 1,378 | — | ||
| Amortization of ROU asset | 170 | 110 | ||
| Amortization of deferred financing costs | 267 | — | ||
| Share-based compensation | 2,763 | 1,859 | ||
| Unrealized gain on derivatives, net | (6,253) | — | ||
| Cash received for derivative settlements, net | 2,136 | — | ||
| Uncollectible account expense | — | 50 | ||
| Deferred income taxes | 8,055 | (7,255) | ||
| (Gain) loss on sale of oil and gas properties | (2,597) | 76 | ||
| Other non-cash items | — | (12) | ||
| Changes in operating assets and liabilities | (3,716) | (10,275) | ||
| Net cash provided by operating activities | 10,758 | 12,766 | ||
| Investing Activities: | ||||
| Cash paid for merger acquisition | (115,646) | — | ||
| Cash paid for drilling and completion | (20,486) | (27,857) | ||
| Cash received for sale of oil and gas properties | 2,949 | 1,140 | ||
| Other | — | (157) | ||
| Net cash used in investing activities | (133,183) | (26,874) | ||
| Financing Activities: | ||||
| Proceeds from credit facility | 87,000 | — | ||
| Proceeds from convertible preferred stock | 35,000 | — | ||
| Proceeds from issuance of shares, net | 139 | — | ||
| Net cash provided by financing activities | 122,139 | — | ||
| Net decrease in cash and restricted cash | (286) | (14,108) | ||
| Cash and restricted cash, beginning of period | 6,607 | 20,715 | ||
| Cash and restricted cash, end of period | $6,321 | $6,607 | ||
RECONCILIATION OF NET (LOSS) INCOME TO ADJUSTED EBITDA
(amounts in thousands)
| Year Ended | Year Ended | |||
| Net (loss) income | ||||
| Add (deduct): | ||||
| Interest expense | 1,407 | — | ||
| Income tax expense (benefit) | 8,055 | (7,255) | ||
| Depreciation, depletion, amortization and accretion | 18,009 | 15,920 | ||
| EBITDA | $17,109 | $20,958 | ||
| Add (deduct): | ||||
| Share-based compensation | 2,763 | 1,859 | ||
| Merger acquisition costs | 7,457 | — | ||
| Impairment of oil and gas properties | 908 | — | ||
| (Gain) loss on sale of oil and gas properties | (2,597) | 76 | ||
| Gain on sale of fixed asset | — | (12) | ||
| Note receivable – credit loss | 1,378 | — | ||
| Adjusted EBITDA | $27,018 | $22,881 | ||
SCHEDULE OF OPEN DERIVATIVE CONTRACTS
As of
(All contracts novated from
CRUDE OIL — Fixed Price Swaps
| Period | Volume (Boe) | Avg. Fixed Price ($/Boe) | |
| Q1 2026 | 171,000 | ||
| Q2 2026 | 126,000 | ||
| Q3 2026 | 180,000 | ||
| Q4 2026 | 105,000 | ||
| Full Year 2026 | 582,000 | $66.43 | |
| Full Year 2027 | 120,000 | ||
CRUDE OIL — Costless Collars
| Period | Volume (Boe) | Floor ($/Boe) | Ceiling ($/Boe) | ||
| Q1 2026 | 79,100 | ||||
| Q2 2026 | 103,200 | ||||
| Q3 2026 | 34,100 | ||||
| Q4 2026 | 53,300 | ||||
| Full Year 2026 | 269,700 | $54.71 | $69.12 | ||
| Full Year 2027 | 68,300 | ||||
CRUDE OIL — Three-Way Collars
| Period | Volume (Boe) | Long Put ($/Boe) | |||||
| Producer Three-Way Collars | |||||||
| Q1 2026 | 36,400 | ||||||
| Q2 2026 | 33,900 | ||||||
| Q3 2026 | 31,800 | ||||||
| Q4 2026 | 29,700 | ||||||
| Full Year 2026 | 131,800 | $45.00 | $55.00 | $67.65 | |||
| Full Year 2027 | 103,000 | ||||||
| Full Year 2026 | 136,600 | ||||||
| Full Year 2027 | 584,500 | ||||||
| Full Year 2028 | 404,200 | ||||||
NATURAL GAS — Fixed Price Swaps
| Period | Volume (Mcf) | Avg. Fixed Price ($/Mcf) | |
| Q2 2026³ | 259,905 | ||
| Q3 2026 | 247,500 | ||
| Q4 2026 | 234,100 | ||
| Full Year 2026 | 741,505 | $3.95 | |
| Full Year 2027 | 562,100 | ||
| Full Year 2028 | 271,100 | ||
NATURAL GAS — Costless Collars
| Period | Volume (Mcf) | Floor ($/Mcf) | Ceiling ($/Mcf) | ||
| Q1 2026 | 232,200 | ||||
| Q2 2026 | 17,800 | ||||
| Q3 2026 | 17,200 | ||||
| Q4 2026 | 18,700 | ||||
| Full Year 2026 | 285,900 | $3.44 | $5.37 | ||
| Full Year 2027 | 282,300 | ||||
| Full Year 2028 | 122,700 | ||||
Derivative Fair Value Summary
| ($ thousands) | Current Portion | Long-Term Portion | ||
| Derivative contract assets | ||||
| Derivative contract liabilities | ||||
| Net derivative asset | $7,404 | $3,282 | ||
| Total net derivative asset (gross assets | $10,686 | |||
¹ 2028 Costless Collar contracts are Participating Three-Way Collars; floor represents long put at
² Participating Three-Way Collars: long put at
³ No natural gas swaps in Q1 2026; collar-only coverage in that quarter (232,200 Mcf).
The Company has not designated any derivative instruments as accounting hedges. Changes in fair value and cash settlements are recognized in earnings under “Net gain (loss) on derivative contracts” in the Consolidated Statements of Operations. For the year ended
CONTACTS:
Media Contact:
(713) 221-1768
PR@pedevco.com
Investor Relations Contact:
Elevate IR
(720) 330-2829
PED@elevate-ir.com
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