Q1 2026 Production Exceeds Expectations on Strong Initial Well Performance
Adjusted EBITDA Increased 404% from Q1 2025(1)
Financial & Operational Highlights
| ($000s except as noted) | Q1 2026 | Q1 2025 | Q4 2025 | Change YoY | Change QoQ |
| Average Daily Production (Boe/d) | 8,091 | 1,707 | 5,310 | +374% | +52% |
| Revenue | +360% | +74% | |||
| Net (Loss) Income | NM(2) | NM(2) | |||
| Adjusted EBITDA(2) | +404% | +40% |
(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.
(2) “NM” means “Not Meaningful.”
- First quarter 2026 production increased 374% to 728,141 Boe (average 8,091 Boe/d), compared to 153,631 Boe (1,707 Boe/d) in the first quarter of 2025, reflecting the first full quarter contribution from the acquired asset base and wells brought online around the transformative merger with certain portfolio companies controlled by
Juniper Capital Advisors, L.P. (the “Juniper Merger”) onOctober 31, 2025 , including stronger-than-expected well performance. - Oil and gas revenue increased 360% to
$40.2 million , compared to$8.7 million in the prior year period, driven by significantly higher production volumes. - First quarter 2026 net loss of
$(25.6) million , or$(3.28) per share, compared to net income of$0.1 million , or$0.03 per share, in the first quarter of 2025, primarily driven by a$31.3 million non-cash net loss on derivative contracts, including$3.4 million of realized losses and$27.9 million of unrealized losses. - Adjusted EBITDA increased 404% to
$21.5 million , compared to$4.3 million in the first quarter of 2025, reflecting higher production volumes from the expanded asset base and development activity, partially offset by higher lease operating expenses and production taxes associated with increased scale. - Net cash provided by operating activities increased 78% to
$10.5 million for the first quarter of 2026, compared to$5.9 million in the first quarter of 2025, driven by higher operating income and cash margins resulting from increased production volumes, partially offset by changes in working capital.
Management Commentary
“Our first full quarter as a combined company following the Juniper Merger delivered results ahead of our internal expectations, which we believe speaks to the outstanding potential of the combined Company’s assets. Production averaged approximately 8,091 Boe per day in the first quarter, driven by strong initial production rates from the 31 D-
“Beyond production outperformance, the combined platform also achieved several of the merger’s key objectives well ahead of schedule. Notably, we delivered Adjusted EBITDA of
“As we look forward through the remainder of 2026, we want to set clear expectations on the cadence of production and our plans moving forward. First quarter production benefited from the timing of D-
________________
3 Exclusion of derivative contract assets and liabilities from working capital is not consistent with GAAP, but is presented to illustrate the impact of derivatives contracts on this figure. See “Use of Non-GAAP Financial Information” and the working capital reconciliation table at the end of this release.
First 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
Loss on Derivative Contracts. The Company recognized a total net loss 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
| Quarter Ended | Quarter Ended | % Change | ||||
| Production Volumes: | ||||||
| Crude Oil (Bbls) | 534,563 | 102,699 | 421 | % | ||
| Natural Gas (Mcf) | 636,057 | 166,733 | 281 | % | ||
| NGL (Bbls) | 87,568 | 23,143 | 278 | % | ||
| Total (Boe) | 728,141 | 153,631 | 374 | % | ||
| Average Daily (Boe/d) | 8,091 | 1,707 | 374 | % | ||
| Average Realized Prices: | ||||||
| Crude Oil ($/Bbl) | (1 | %) | ||||
| Natural Gas ($/Mcf) | (41 | %) | ||||
| NGL ($/Bbl) | (43 | %) | ||||
Operational Update
The Company delivered strong operational performance in the first quarter of 2026, with consolidated production outperforming the Company’s internal plan and lease operating expense (“LOE”) tracking at or below budget in our operating regions. The Company continued to identify cost savings and operational efficiencies across its asset base, which are expected to support continued performance through the balance of the year.
D-
Powder River Basin (“PRB”). The Company holds approximately 202,100 net acres and holds interests in 156 gross (135.4 net) wells in the PRB, of which 16 gross (1.4 net) are non-operated. PRB production outperformed the Company’s internal plan during the first quarter, with no major downtime or operational issues during the quarter and the asset benefiting from a relatively mild winter. There was no operated drilling or completion activity during the first quarter; the Company continues to evaluate its inventory of development opportunities across its substantial PRB position.
Liquidity and Capital Structure
As of
During the first quarter of 2026, the Company drew down
Net cash provided by operating activities was
Earnings Conference Call
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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; 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 and Adjusted EBITDA, 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 adjusted to exclude share-based compensation, impairment of oil and gas properties, net (gain) loss on derivative contracts adjusted for cash settlements, 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 (loss) income to Adjusted EBITDA is provided at the end of this release.
This press release also includes Working Capital (Deficit) Excluding Derivative Contract Assets and Liabilities as a supplemental measure of the Company’s liquidity. This measure is calculated as total current assets less total current liabilities, excluding current derivative contract assets and current derivative contract liabilities. The Company believes this measure provides investors with a more meaningful view of operational working capital by removing the effects of mark-to-market changes in the Company’s commodity price derivative contracts, which can vary significantly from period to period based on forward commodity price movements and do not reflect operational cash obligations or liquidity in the same manner as other working capital components. Working Capital (Deficit) Excluding Derivative Contract Assets and Liabilities has limitations and should not be considered in isolation or as a substitute for analysis of the Company’s liquidity as reported under GAAP. The most directly comparable GAAP measure is working capital (deficit) (total current assets less total current liabilities), which is presented with equal or greater prominence in this release. The Company’s calculation of this measure may differ from similarly titled measures used by other companies. A reconciliation of working capital (deficit) to working capital (deficit) excluding derivative contract assets and liabilities is provided at the end of this release.
CONSOLIDATED BALANCE SHEETS (amounts in thousands, except share and per share data) | ||||||||
| (Unaudited) | 2025 | |||||||
| Assets | ||||||||
| Current assets: | ||||||||
| Cash | $ | 7,702 | $ | 3,222 | ||||
| Restricted cash | 3,634 | - | ||||||
| Accounts receivable – oil and gas | 27,407 | 25,666 | ||||||
| Inventory | 141 | 61 | ||||||
| Derivative contract assets, current | 3,340 | 8,368 | ||||||
| Prepaid expenses and other current assets | 307 | 434 | ||||||
| Total current assets | 42,531 | 37,751 | ||||||
| Oil and gas properties: | ||||||||
| Oil and gas properties, subject to amortization, net | 301,525 | 303,411 | ||||||
| Oil and gas properties, not subject to amortization, net | 15,861 | 18,859 | ||||||
| Total oil and gas properties, net | 317,386 | 322,270 | ||||||
| Derivative contract assets | 7,585 | 9,640 | ||||||
| Operating lease – right-of-use asset | 169 | 213 | ||||||
| Deferred income taxes | 96 | - | ||||||
| Other assets | 2,316 | 5,995 | ||||||
| Total assets | $ | 370,083 | $ | 375,869 | ||||
| Liabilities and Shareholders’ Equity | ||||||||
| Current liabilities: | ||||||||
| Accounts payable | $ | 9,922 | $ | 32,436 | ||||
| Accrued expenses | 12,418 | 8,245 | ||||||
| Revenue payable | 22,947 | 21,480 | ||||||
| Income tax payable | 28 | - | ||||||
| Operating lease liabilities – current | 170 | 182 | ||||||
| Derivative contract liabilities – current | 16,764 | 964 | ||||||
| Asset retirement obligations – current | 714 | 1,170 | ||||||
| Total current liabilities | 62,963 | 64,477 | ||||||
| Long-term liabilities: | ||||||||
| Revolving credit facility | 98,000 | 87,000 | ||||||
| Operating lease liabilities, net of current portion | - | 32 | ||||||
| Derivative contract liabilities | 11,366 | 6,358 | ||||||
| Asset retirement obligations, net of current portion | 13,341 | 7,641 | ||||||
| Deferred income taxes | - | 800 | ||||||
| Other long-term liabilities | 2,228 | 2,197 | ||||||
| Total liabilities | 187,898 | 168,505 | ||||||
| Commitments and contingencies (Note 12) | ||||||||
| Shareholders’ equity: | ||||||||
| Series A preferred stock, | - | 17,014 | ||||||
| Common stock, | 13 | 5 | ||||||
| Additional paid-in capital | 329,659 | 312,205 | ||||||
| Accumulated deficit | (147,487 | ) | (121,860 | ) | ||||
| Total shareholders’ equity | 182,185 | 207,364 | ||||||
| Total liabilities and shareholders’ equity | $ | 370,083 | $ | 375,869 | ||||
CONSOLIDATED STATEMENTS OF OPERATIONS (amounts in thousands, except per share data) | ||||||||
| Three Months Ended | ||||||||
| 2026 | 2025 | |||||||
| Revenue: | ||||||||
| Oil and gas sales | $ | 40,222 | $ | 8,736 | ||||
| Operating expenses: | ||||||||
| Lease operating costs | 16,357 | 3,412 | ||||||
| Selling, general and administrative expense | 3,107 | 1,596 | ||||||
| Depreciation, depletion, amortization and accretion | 12,450 | 3,346 | ||||||
| Impairment of oil and gas properties | 1,605 | 232 | ||||||
| Total operating expenses | 33,519 | 8,586 | ||||||
| Operating income | 6,703 | 150 | ||||||
| Other income (expense): | ||||||||
| Interest expense | (1,995 | ) | - | |||||
| Interest income | 58 | 64 | ||||||
| Net loss on derivative contracts | (31,266 | ) | - | |||||
| Other income (expense) | 5 | 2 | ||||||
| Total other (expense) income | (33,198 | ) | 66 | |||||
| (Loss) Income before income taxes | (26,495 | ) | 216 | |||||
| Income tax benefit (expense) | 868 | (76 | ) | |||||
| Net (loss) income | $ | (25,627 | ) | $ | 140 | |||
| (Loss) earnings per common share: | ||||||||
| Basic | $ | (3.28 | ) | $ | 0.03 | |||
| Diluted | $ | (3.28 | ) | $ | 0.03 | |||
| Weighted average number of common shares outstanding: | ||||||||
| Basic | 7,815,752 | 4,543,406 | ||||||
| Diluted | 7,815,752 | 4,543,406 | ||||||
CONSOLIDATED STATEMENTS OF CASH FLOWS (amounts in thousands) | ||||||||
| Three Months Ended | ||||||||
| 2026 | 2025 | |||||||
| Cash Flows From Operating Activities: | ||||||||
| Net (loss) income | $ | (25,627 | ) | $ | 140 | |||
| Adjustments to reconcile net income to net cash provided by operating activities: | ||||||||
| Depreciation, depletion, amortization and accretion | 12,450 | 3,346 | ||||||
| Impairment of oil and gas properties | 1,605 | 232 | ||||||
| Amortization of right-of-use asset | 48 | 28 | ||||||
| Amortization of deferred financing costs | 168 | - | ||||||
| Share-based compensation expense | 492 | 475 | ||||||
| Net loss on derivative contracts | 31,266 | - | ||||||
| Cash received for derivative settlements, net | 158 | - | ||||||
| Deferred income taxes | (896 | ) | 76 | |||||
| Changes in operating assets and liabilities: | ||||||||
| Accounts receivable – oil and gas | (1,741 | ) | (3,853 | ) | ||||
| Note receivable accrued interest | - | (41 | ) | |||||
| Inventory | (80 | ) | - | |||||
| Prepaid expenses and other current assets | 521 | 81 | ||||||
| Accounts payable | (16,977 | ) | (3,154 | ) | ||||
| Accrued expenses | 7,622 | 6,432 | ||||||
| Revenue payable | 1,467 | 2,166 | ||||||
| Income tax payable | 28 | - | ||||||
| Other liabilities | 31 | - | ||||||
| Net cash provided by operating activities | 10,535 | 5,928 | ||||||
| Cash Flows From Investing Activities: | ||||||||
| Cash paid for drilling and completion costs | (16,476 | ) | (1,403 | ) | ||||
| Cash received for sale of oil and gas property | - | 2,028 | ||||||
| Net cash (used in) provided by investing activities | (16,476 | ) | 625 | |||||
| Cash Flows From Financing Activities: | ||||||||
| Proceeds from credit facility | 11,000 | - | ||||||
| Reverse stock split costs | (44 | ) | - | |||||
| Net cash provided by financing activities | 10,956 | - | ||||||
| Net increase in cash and restricted cash | 5,015 | 6,553 | ||||||
| Cash and restricted cash at beginning of period | 6,321 | 6,607 | ||||||
| Cash and restricted cash at end of period | $ | 11,336 | $ | 13,160 | ||||
| Supplemental Disclosure of Cash Flow Information | ||||||||
| Cash paid for: | ||||||||
| Interest | $ | 1,147 | $ | - | ||||
| Income taxes | $ | - | $ | - | ||||
| Noncash investing and financing activities: | ||||||||
| Change in accrued oil and gas development costs | $ | 12,683 | $ | 4,277 | ||||
| Changes in estimates of asset retirement costs, net | $ | 4,474 | $ | 1,085 | ||||
| Conversion of preferred stock into common stock | $ | 17,014 | $ | - | ||||
| Issuance of restricted common stock | $ | - | $ | 1 | ||||
RECONCILIATION OF NET (LOSS) INCOME TO ADJUSTED EBITDA (amounts in thousands) | |||||||
| Three Months Ended | |||||||
| 2026 | 2025 | ||||||
| Net (loss) income | $ | (25,627 | ) | $ | 140 | ||
| Add (deduct) | |||||||
| Interest expense | 1,995 | - | |||||
| Income tax (benefit) expense | (868 | ) | 76 | ||||
| Depreciation, depletion, amortization and accretion | 12,450 | 3,346 | |||||
| EBITDA | (12,050 | ) | 3,562 | ||||
| Add (deduct) | |||||||
| Share-based compensation | 492 | 475 | |||||
| Merger acquisition costs | 200 | - | |||||
| Impairment of oil and gas properties | 1,605 | 232 | |||||
| Net loss on derivative contracts | 31,266 | - | |||||
| Adjusted EBITDA | $ | 21,513 | $ | 4,269 | |||
RECONCILIATION OF WORKING CAPITAL (DEFICIT) TO WORKING CAPITAL (DEFICIT) EXCLUDING DERIVATIVE CONTRACT ASSETS AND LIABILITIES (amounts in thousands) | ||||||||
| (Unaudited) | ||||||||
| Total current assets | $ | 42,531 | $ | 37,751 | ||||
| Less: Total current liabilities | (62,963 | ) | (64,477 | ) | ||||
| Working capital (deficit) (GAAP) | (20,432 | ) | (26,726 | ) | ||||
| Adjustments: | ||||||||
| Less: Derivative contract assets, current | (3,340 | ) | (8,368 | ) | ||||
| Add: Derivative contract liabilities, current | 16,764 | 964 | ||||||
| Working capital (deficit) excluding derivative contract assets and liabilities | $ | (7,008 | ) | $ | (34,130 | ) | ||
SCHEDULE OF OPEN DERIVATIVE CONTRACTS As of (All contracts novated from | |||||||||||
| Crude Oil - 3 Way Collars | |||||||||||
| Producer Three-Way Collars (Summary of 3 separate contracts) | Participating Three-Way Collars (Summary of 3 separate contracts) | ||||||||||
| Date | Volume (Boe) | Put Sold ($/Boe) | Put Bought ($/Boe) | Call Sold ($/Boe) | Volume (Boe) | Put Bought ($/Boe) | Call Sold ($/Boe) | Call Bought ($/Boe) | |||
| 2Q 2026 | 33,900 | 23,700 | |||||||||
| 3Q 2026 | 31,800 | 24,400 | |||||||||
| 4Q 2026 | 29,700 | 66,900 | |||||||||
| FY 2026 | 95,400 | $45.00 | $55.00 | $67.65 | 115,000 | $54.00 | $62.50 | $80.00 | |||
| 1Q 2027 | 27,400 | 127,700 | |||||||||
| 2Q 2027 | 26,200 | 163,700 | |||||||||
| 3Q 2027 | 25,200 | 163,300 | |||||||||
| 4Q 2027 | 24,200 | 129,800 | |||||||||
| FY 2027 | 103,000 | $45.00 | $55.00 | $71.55 | 584,500 | $54.00 | $62.50 | $80.00 | |||
| 1Q 2028 | - | - | - | - | 114,100 | ||||||
| 2Q 2028 | - | - | - | - | 128,000 | ||||||
| 3Q 2028 | - | - | - | - | 123,000 | ||||||
| 4Q 2028 | - | - | - | - | 39,100 | ||||||
| FY 2028 | - | - | - | - | 404,200 | $54.00 | $62.50 | $80.00 | |||
| Crude Oil - Swaps and Costless Collars | |||||
| Swaps | Costless Collars | ||||
| Date | Volume (Boe) | Avg. Price ($/Boe) | Volume (Boe) | Floor Price ($/Boe) | Ceiling Price ($/Boe) |
| 2Q 2026 | 126,000 | 168,523 | |||
| 3Q 2026 | 180,000 | 71,170 | |||
| 4Q 2026 | 105,000 | 77,083 | |||
| FY 2026 | 411,000 | $67.43 | 316,776 | $54.71 | $69.12 |
| 1Q 2027 | 30,000 | 54,900 | |||
| 2Q 2027 | 30,000 | 9,900 | |||
| 3Q 2027 | 30,000 | 1,700 | |||
| 4Q 2027 | 30,000 | 1,800 | |||
| FY 2027 | 120,000 | $64.90 | 68,300 | $54.00 | $64.00 |
| 1Q 2028 | - | - | - | - | - |
| 2Q 2028 | - | - | - | - | - |
| 3Q 2028 | - | - | - | - | |
| 4Q 2028 | - | - | - | - | - |
| FY 2028 | - | - | - | - | - |
| Natural Gas | |||||
| Swaps | Costless Collars | ||||
| Date | Volume (Mcf) | Avg. Price ($/mcf) | Volume (Mcf) | Floor Price ($/mcf) | Ceiling Price ($/mcf) |
| 2Q 2026 | 259,905 | 17,800 | |||
| 3Q 2026 | 247,500 | 17,200 | |||
| 4Q 2026 | 234,100 | 18,700 | |||
| FY 2026 | 741,505 | $3.95 | 53,700 | $3.50 | $5.21 |
| 1Q 2027 | - | 237,000 | |||
| 2Q 2027 | 209,000 | 16,900 | |||
| 3Q 2027 | 201,900 | 16,900 | |||
| 4Q 2027 | 151,200 | 11,500 | |||
| FY 2027 | 562,100 | $3.74 | 282,300 | $4.00 | $5.15 |
| 1Q 2028 | - | - | 122,700 | ||
| 2Q 2028 | 118,100 | - | - | - | |
| 3Q 2028 | 115,100 | - | - | - | |
| 4Q 2028 | 37,900 | - | - | - | |
| FY 2028 | 271,100 | $3.49 | 122,700 | $4.00 | $4.62 |
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 period ended
CONTACTS:
Media Contact:
(713) 221-1768
PR@pedevco.com
Investor Relations Contact:
Elevate IR
(720) 330-2829
PED@elevate-ir.com
Source:
