UNITED
STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM
OF THE SECURITIES EXCHANGE ACT OF 1934
For
the fiscal year ended
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _____________ to _____________
Commission
File Number
(Exact name of registrant as specified in its charter)
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Securities registered pursuant to Section 12(b) of the Act:
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Securities registered pursuant to 12(g) of the Act: None
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Indicate
by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☐ Yes
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by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. ☐ Yes
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by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange
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405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant
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Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and “emerging growth company” in Rule 12b-2 of the Exchange Act.
| Large accelerated filer ☐ | Accelerated filer ☐ | Smaller reporting company
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Emerging growth company |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐
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by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).
The aggregate market value of the voting and non-voting common equity held
by non-affiliates, computed by reference to the closing sales price of such common equity as of the last business day of the registrant's
most recently completed second fiscal quarter, was $
The number of shares of the registrant's common stock, $0.001 par value, outstanding as of March 25, 2025 was .
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant’s definitive Proxy Statement relating to the registrant’s 2025 annual meeting of stockholders have been incorporated by reference into Part III of this Annual Report on Form 10-K.
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EMPIRE PETROLEUM CORPORATION
FORM 10-K
TABLE OF CONTENTS
2
FORWARD-LOOKING STATEMENTS
Certain statements in this Annual Report on Form 10-K constitute "forward-looking statements” within the meaning Section 27A of the Securities Act of 1933, as amended (the "Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act”). Additionally, forward-looking statements may be made orally or in press releases, conferences, reports, on our website or otherwise, in the future by us or on our behalf. All statements, other than statements of historical facts, which address activities, events, or developments that Empire expects, believes, or anticipates will or may occur in the future, including future sources of financing and other possible business developments, are forward-looking statements.
By their very nature, forward-looking statements require management to make assumptions that may not materialize or that may not be accurate. Forward-looking statements are subject to known and unknown risks and uncertainties and other factors that may cause actual results, levels of activity and achievements to differ materially from those expressed or implied by such forward-looking statements. Factors that could cause actual results to differ materially from the results discussed in such forward-looking statements include, but are not limited to, those discussed in Item 1A (“Risk Factors”) and elsewhere in this Form 10-K and in other documents that we file with or furnish to the Securities and Exchange Commission (the “SEC”), and the following:
| · | changes in oil, natural gas and natural gas liquids prices and the demand for oil, natural gas and natural gas liquids; |
| · | our ability to replace reserves and efficiently develop current reserves; |
| · | uncertainties inherent in estimating oil and gas reserves; |
| · | management’s ability to execute our business plan; |
| · | delays and other difficulties related to producing oil, natural gas and natural gas liquids; |
| · | delays and other difficulties related to regulatory and governmental approvals and restrictions; |
| · | availability of sufficient capital to execute management’s business plan, including future cash flows from operations, available borrowing capacity under revolving credit facilities, from our two largest stockholders and otherwise; |
| · | management's ability to make acquisitions on economically acceptable terms and management's ability to integrate acquisitions; |
| · | weather and environmental conditions; |
| · | unforeseen engineering, mechanical or technological difficulties in working over wells; |
| · | costs of operations and operating hazards; |
| · | competition from other natural resource companies; |
| · | unanticipated reductions in the borrowing base under the revolving credit facility we are party to; |
| · | the availability of sufficient pipeline and other transportation facilities and equipment to carry our production to market and the impact of these facilities on our realized prices; |
| · | our ability to retain key members of senior management and key technical and financial employees; |
| · | the identification of and severity of adverse events and governmental responses to these or other environmental events; |
| · | future Environmental, Social and Governance compliance developments and increased attention to such matters which could adversely affect our ability to raise equity and debt capital; |
| · | the effect of our derivative activities; |
| · | impacts of public health crises, pandemics and epidemics, such as the coronavirus pandemic ("COVID-19"); |
| · | A cyber incident involving our information systems and related infrastructure, or that of our business partners; |
| · | the effects of governmental and environmental regulation; and |
| · | general economic conditions including inflation, tariffs and interest rates. |
All forward-looking statements are expressly qualified in their entirety by the cautionary statements in this section and elsewhere in this Form 10-K. Other than as required by applicable securities laws, we undertake no duty to update these forward-looking statements, whether as a result of new information, subsequent events or circumstances, changes in expectations, or otherwise. Readers should not place undue reliance on these forward-looking statements. All forward-looking statements speak only as of the date of this report or, if earlier, as of the date they were made.
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GLOSSARY OF TERMS
The following are abbreviations and definitions of certain terms used within this Annual Report on Form 10-K.
ASC – Accounting Standards Codification.
ASU – Accounting Standards Update.
Basin – A large natural depression on the earth’s surface in which sediments, generally brought by water, accumulate.
Bbl – One barrel or 42 U.S. gallons liquid volume of oil or other liquid hydrocarbons.
Boe – Barrel of oil equivalent, determined using a ratio of six Mcf of natural gas equal to one barrel of oil equivalent. The ratio does not assume price equivalency and, given price differentials, the price for a barrel of oil equivalent for natural gas differs significantly from the price for a barrel of oil. A barrel of NGLs also differs significantly in price from a barrel of oil.
CG&A – Cawley, Gillespie & Associates, Inc.
Completion – The process of treating a drilled well followed by the installation of permanent equipment for the production of oil or natural gas, or in the case of a dry hole, the reporting of abandonment to the appropriate agency.
DD&A – Depreciation, depletion and amortization.
Development Well – A well drilled within the proved area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive.
EPA – United States Environmental Protection Agency.
ESG – Environmental, Social and Governance.
Exploratory Well – A well drilled to find and produce oil or gas in an unproved area, to find a new reservoir in a field previously found to be productive of oil or gas in another reservoir, or to extend a known reservoir. Generally, a well that is not a development well, a service well, or a stratigraphic test well.
FASB – Financial Accounting Standards Board.
Federal Deposit Insurance Corporation or FDIC – An independent agency created by the Congress to maintain stability and public confidence in the nation’s financial system. The FDIC insures deposits; examines and supervises financial institutions for safety, soundness, and consumer protection; makes large and complex financial institutions resolvable; and manages receiverships.
Field – An area consisting of a single reservoir or multiple reservoirs all grouped on or related to the same individual geological structural feature and/or stratigraphic condition.
GHG – Greenhouse gas.
LOE – Lease Operating Expense, a current period expense incurred to operate a well.
MBbls – One thousand barrels of crude oil or other liquid hydrocarbons.
MBoe – One thousand barrels of oil equivalent, determined using a ratio of six Mcf of natural gas equal to one barrel of oil equivalent.
MMBoe – One million barrels of oil equivalent, determined using a ratio of six Mcf of natural gas equal to one barrel of oil equivalent.
Mcf – One thousand cubic feet.
MMcf – One million cubic feet.
National Institute of Standards and Technology or NIST – An agency of the United States Department of Commerce whose mission is to promote American innovation and industrial competitiveness.
Net acres or net wells – The sum of the fractional working interests owned in gross acres or gross wells.
New York Mercantile Exchange – A commodity futures exchange owned and operated by CME Group of Chicago.
NYSE American – NYSE American Stock Exchange.
NGLs – Natural gas liquids measured in barrels. NGLs are made up of ethane, propane, isobutane, normal butane and natural gasoline, each of which have different uses and different pricing characteristics.
Net revenue interest or NRI –The total revenue interest controlled by an entity in a specific oil or gas production unit, including a well, lease, or drilling unit.
New Mexico Oil Conservation Division – The New Mexico Oil Conservation Division regulates oil and gas activity in New Mexico. The Division gathers well production data, permits new wells, enforces the division’s rules and the state’s oil and gas statutes, makes certain abandoned wells are properly plugged, and ensures the land is responsibly restored.
Operator – An oil and gas joint venture participant that manages the joint venture, pays venture costs, and bills the venture’s non-operators for their share of venture costs. The operator is also responsible to market all oil, gas, and NGLs production, except for those non-operators who take their production in-kind.
OTCQB – The over-the-counter (“OTC”) market exchange for the middle tier of three marketplaces for trading OTC stocks.
Overriding Royalty Interest or ORRI – A royalty interest that is created out of the operating or working interest. Unlike a royalty interest, an overriding royalty interest terminates with the operating interest from which it was created or carved out of.
Plugging and abandonment or P&A – Refers to the sealing off of fluids in the strata penetrated by a well so that the fluids from one stratum will not escape into another stratum or to the surface.
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Proved developed producing reserves or PDP – Reserves that can be expected to be recovered from existing wells and completions with existing equipment and operating methods.
Proved undeveloped reserves – Reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required.
PV-10 – The present value, discounted at 10% per annum, of future net revenues (estimated future gross revenues less estimated future costs of production, development, and asset retirement costs) associated with reserves and is not necessarily the same as market value. PV-10 does not include estimated future income taxes. Unless otherwise noted, PV-10 is calculated using the pricing scheme required by the SEC. PV-10 of proved reserves is calculated the same as the standardized measure of discounted future net cash flows, except that the standardized measure of discounted future net cash flows includes future estimated income taxes discounted at 10% per annum.
Reasonable Certainty – A high degree of confidence.
Recompletion – The process of re-entering an existing wellbore that is either producing or not producing and completing in new reservoirs in an attempt to establish or increase existing production.
Reservoir – A porous and permeable underground formation containing a natural accumulation of producible oil and/or natural gas that is confined by impermeable rock or water barriers and is separate from other reservoirs.
Royalty Interest or RI – The mineral owner’s share of production, free of costs, but subject to severance taxes unless the lessor is a government.
SEC – United States Securities and Exchange Commission.
Standardized Measure – The present value of estimated future net revenue to be generated from the production of proved reserves, determined in accordance with the rules and regulations of the SEC (using prices and costs in effect as of the date of estimation), less future development, production and income tax expenses, and discounted at 10% per annum to reflect the timing of future net revenue.
Undeveloped acreage – Lease acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil and natural gas regardless of whether such acreage contains proved reserves.
Working interest or WI – The ownership interest, generally defined in a Joint Operating Agreement (“JOA”), that gives the owner the right to drill, produce and/or conduct operating activities on the property and share in the sale of production, subject to all royalties, overriding royalties and other burdens and obligates the owner of the interest to share in all costs of exploration, development operations and all risks in connection therewith.
Workover – Operations on a producing or injection well to restore or increase production.
WTI – West Texas Intermediate.
XTO – XTO Holdings, LLC, a subsidiary of ExxonMobil.
Energy equivalent is determined by using the ratio of one barrel of crude oil, condensate or NGLs to six Mcf of natural gas.
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PART I
ITEM 1. BUSINESS.
In this Form 10-K, references to “Empire”, the “Company”, “we”, “our”, and “us” refer to Empire Petroleum Corporation and its wholly-owned subsidiaries, unless context indicates otherwise.
Overview
Empire Petroleum Corporation is an independent energy company that engages in unlocking value in developed assets. Empire operates the following wholly-owned subsidiaries in its areas of operations:
| ● | Empire New Mexico LLC (“Empire New Mexico”), consisting of the following entities: |
| ○ | Empire New Mexico LLC d/b/a Green Tree New Mexico | |
| ○ | Empire EMSU LLC | |
| ○ | Empire EMSU-B LLC | |
| ○ | Empire AGU LLC | |
| ○ | Empire NM Assets LLC |
| ● | Empire North Dakota (“Empire North Dakota”), consisting of the following entities: |
| ○ | Empire North Dakota LLC (“Empire North Dakota”) |
| ○ | Empire ND Acquisition LLC (“Empire NDA”) |
| ● | Empire Texas (“Empire Texas”), consisting of the following entities: |
| ○ | Empire Texas LLC |
| ○ | Empire Texas Operating LLC |
| ○ | Empire Texas GP LLC |
| ○ | Pardus Oil & Gas Operating, LP (owned 1% by Empire Texas GP LLC and 99% by Empire Texas LLC) |
| ● | Empire Louisiana LLC (“Empire Louisiana”) |
Empire was incorporated in the state of Delaware in 1985. The consolidated financial statements of Empire Petroleum Corporation and subsidiaries include the accounts of the Company and its wholly-owned subsidiaries.
Our mission is to increase shareholder value by building oil and natural gas reserves in strategic plays in the United States. To accomplish its mission, we plan to execute the following business strategies:
| ● | Cost-effectively optimize well production |
| ● | Reduce unit operating costs and improve margins |
| ● | Target proved developed producing acquisitions in predictable fields that have historically had low production decline and long lives |
| ● | Focus on high-quality assets that add scale and provide synergies to our existing portfolio and core areas of operation |
We operate as a single operating segment. For additional information, see Note 18 – Segment Reporting of Notes to Consolidated Financial Statements.
Available Information
Our Annual Report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act, as well as proxy statements and other information we file with, or furnish to, the SEC are available free of charge on our website at www.empirepetroleumcorp.com. We make these documents available as soon as reasonably practicable after we electronically file them with, or furnish them to, the SEC. The information contained on our website, or available by hyperlink from our website, is not incorporated into this Form 10-K or other documents we file with, or furnish to, the SEC. We intend to use our website as a means of disclosing material non-public information and for complying with our disclosure obligations under Regulation Fair Disclosure. Such disclosures will be included on our website in the “Investor Relations” sections. Accordingly, investors should monitor such portions of our website, in addition to following our press releases, SEC filings and public conference calls and webcasts.
In addition, we use social media to communicate with our investors and the public about our company, our businesses and our results of operations. The information we post on social media could be deemed to be material information. Therefore, we encourage investors, the media and others interested in our company to review the information we post on the social media channels listed in the “Investor Relations” section of our website.
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Properties
We are an independent operator in four geographic areas in the United States. For our operated properties, we manage and influence production using a combination of experienced field personnel and third-party service providers to execute our mission. Our producing properties have reasonably predictable production profiles and cash flows, subject to commodity price and cost fluctuations.
As is common in the industry in which we operate, we selectively participate in drilling and developmental activities in non-operated properties. Decisions to participate in non-operated properties are made after technical and economic analysis of the projects which also considers the operating expertise and historical track record of the operators.
Empire New Mexico
Empire New Mexico was formed when we purchased producing assets from XTO in May 2021. These assets are located in Lea County, New Mexico, and include approximately 714 gross (529 net) producing and injection wells on a contiguous and consolidated acreage position consisting of 48,000 gross (41,000 net). We also have 15 royalty interest (“RI”) wells with an average overriding royalty interest (“ORRI”) of 0.6%. Empire New Mexico’s assets primarily produce oil with accompanying natural gas and NGLs production. Empire New Mexico’s properties are located in Grayburg/San Andres (primary source of production), Queen-Seven Rivers-Yates, Devonian, Abo, Blineberry, Tubb, and Drinkard formations.
Empire North Dakota
Empire North Dakota includes approximately 232 gross (108 net) producing or injection wells on 24,480 gross (18,480 net) acres in North Dakota and western Montana. We also have smaller nonoperating interests in 106 gross (less than 1 net) vertical wells. These properties primarily produce oil with some related gas production. Assets are located in Madison (primary source of production), Bakken, Duperow, Red River, and Ratcliffe/Mission Canyon formations.
The existing producing properties have experienced near-flat production rates over the last five years. We have been able to capitalize on operational improvements to allow a more immediate recovery of reserves.
In the fourth quarter of 2023, the Company commenced a program to further develop its Starbuck Field located in North Dakota (the “Starbuck Drilling Program”). The Starbuck Drilling Program’s first well came online in December 2023 and a total of 13 wells in the Upper Charles formation have been placed in production as of the filing date of this report. The Company is currently optimizing completions while increasing the core production through its enhanced oil recovery (“EOR”) program.
As the Starbuck Field is strategically designed for EOR production, the Company has experienced an increase in production throughout 2024 which is anticipated to continue into 2025.
Empire has also logged five vertical pilot wells to help identify additional pay and extend existing reservoirs, which has confirmed three additional primary zones of interest and two secondary zones of interest. In addition, the Company has drilled a vertical appraisal well in the Starbuck Field to core two new target zones for development. The two new primary target zones of development have been successfully cored and the cores are under analysis. The data will then be added to a future development plan while the vertical wells have been placed in production during 2024.
Empire Texas
Empire Texas includes approximately 119 gross (106 net) producing wells on approximately 43,000 gross (30,000 net) acres as well as 77 miles of gathering lines and pipelines with related facilities and equipment. Empire Texas owns concentrated acreage and stacked pay in the historically prolific East Texas Basin. Assets are concentrated in the Fort Trinidad Field in Houston and Madison Counties with high working interest and historical production from eight separate formations. We have begun technical work for uplift opportunities in Texas.
In the fourth quarter of 2024, the Company initiated a return-to-production program on four wells primarily focused on facility work on the existing saltwater disposal system.
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Empire Louisiana
Empire Louisiana includes 7 gross (5 net) producing wells and three saltwater disposal wells in the Miocene, Frio, Cockfield, and Wilcox formations. Empire Louisiana’s assets primarily produce oil.
Production and Operating Data
The following table sets forth a summary of our production and operating data. Because of normal production declines, increased or decreased production due to future acquisitions, divestitures, and development, fluctuations in commodity prices and the effects of acquisitions or divestitures, the historical information presented below should not be interpreted as being indicative of future results.
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
Production and operating data:
| ||||||||
Net sales volumes: | ||||||||
| Oil (Bbl) | 581,159 | 487,869 | ||||||
| Natural gas (Mcf) | 916,955 | 854,274 | ||||||
| Natural gas liquids (Bbl) | 150,091 | 136,013 | ||||||
| Total (Boe) | 884,076 | 766,261 | ||||||
| Average price per unit: | ||||||||
| Oil (1) | $ | 71.44 | $ | 75.19 | ||||
| Natural gas | $ | 0.37 | $ | 2.02 | ||||
| Natural gas liquids | $ | 14.21 | $ | 12.21 | ||||
| Total (Boe) | $ | 49.76 | $ | 52.29 | ||||
| Operating costs and expenses per Boe: | ||||||||
| Lease operating expense (excluding workovers) | $ | 24.46 | $ | 21.70 | ||||
| Workovers | $ | 6.71 | $ | 15.65 | ||||
| Total Lease operating expense | $ | 31.16 | $ | 37.36 | ||||
| Production and ad valorem taxes | $ | 4.26 | $ | 3.97 | ||||
| Depreciation, depletion, amortization and accretion | $ | 12.74 | $ | 6.33 | ||||
| General & administrative (excluding stock-based compensation) | $ | 14.23 | $ | 15.71 | ||||
| Stock-based compensation | $ | 2.44 | $ | 4.10 | ||||
| Total General & administrative | $ | 16.67 | $ | 19.81 | ||||
(1) Excludes the effect of net cash receipts from (payments on) derivatives.
At December 31, 2024 and 2023, we had approximately 1,072 gross (748 net) producing and injection wells.
We have no firm delivery commitments for oil or natural gas.
Oil and Natural Gas Reserves
Our primary mission is to optimize existing producing properties; as such, there are no reserves estimated for undeveloped properties, though we own acreage that can be drilled in the future and are also a non-operator WI owner on acreage subject to future drilling activities. The following table represents our oil and natural gas reserves:
| Oil | Natural Gas | NGLs | Total | |
| (MBbl) | (MMcf) | (MBbl) | MBoe | |
| Proved developed at December 31, 2024 | 7,001 | 6,064 | 1,215 | 9,227 |
| Proved developed at December 31, 2023 | 6,924 | 6,104 | 1,171 | 9,112 |
Net proved reserves were calculated using an unweighted arithmetic average of the first-day-of-the-month price within the 12-month period for the year. All prices and costs associated with operating wells were held constant in accordance with SEC guidelines. Prices of $71.66 per barrel of oil, $0.95 per Mcf and $24.54 per barrel of NGLs were utilized at December 31, 2024. Prices of $75.45 per barrel of oil, $1.51 per Mcf and $9.82 per barrel of NGLs were utilized at December 31, 2023.
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Reserve Estimation Process
Reserve estimation is a subjective process as the underground accumulations of crude oil and natural gas cannot be measured in an exact manner, and the accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Estimates of economically recoverable oil and natural gas reserves depend on several variable factors, including but not limited to historical production from the area compared with production from other producing areas, and assumptions about: reservoir size; the effects of regulations by governmental agencies; future oil and natural gas prices; future operating costs; severance and excise taxes; operational risks; development costs; and workover and remedial costs.
Some or all of these assumptions may vary considerably from actual results. For these and other reasons, estimates of the economically recoverable quantities of oil and natural gas attributable to any group of properties, classifications of those oil and natural gas reserves based on the risk of recovery, and estimates of the future net cash flows from oil, and natural gas reserves prepared by different engineers or by the same engineers but at different times may vary substantially. Such estimates may be subject to periodic downward or upward adjustments. Actual production, revenues, and expenditures regarding our oil, NGLs, and natural gas reserves will likely vary from estimates, and those variances may be material.
We engage and consult with an independent petroleum engineering firm, CG&A, to prepare our annual reserve estimates and rely on CG&A’s expertise to ensure that reserve estimates are prepared in accordance with SEC guidelines. The technical person primarily responsible for the preparation of the reserve report is Zane Meekins, Executive Vice President. Mr. Meekins has been with CG&A since 1989 and graduated from Texas A&M University in 1987 with a bachelor’s degree in petroleum engineering. He is a registered professional engineer in Texas and has more than 30 years of experience in the estimation and evaluation of oil and natural gas reserves. He is also a member of the Society of Petroleum Engineers and the Society of Petroleum Evaluation Engineers.
The primary inputs to the reserve estimation process are technical information, financial data, ownership interest and production data. The relevant field and reservoir technical information, which is updated at least annually, is assessed for validity when CG&A has technical meetings with our personnel. Our accounting records, operational data and well information used in the reserve estimation process are subject to internal and external quarterly reviews, annual audits, and internal controls over financial reporting. Our reserves database is updated and maintained by our Senior Reserves Engineer who has the appropriate technical qualifications to maintain and assist in the preparation of reserve estimates. The Senior Reserves Engineer has over 40 years of industry experience, a degree in engineering from Tulane University in 1978, a licensed professional, and holds several memberships in professional petroleum engineer organizations. Once the reserves database has been appropriately updated, Empire will meet with CG&A who will then review the relevant information and validate the estimates. CG&A will work with the Senior Reserves Engineer to resolve any differences in reserve estimates. CG&A will then finalize the reserve report once any differences are resolved and provide a final report to the Company.
Marketing Arrangements
We market our oil and natural gas in accordance with standard energy industry practices. This marketing effort endeavors to obtain the combined highest netback and most secure market available at that time.
We sell oil production at the lease locations to third-party purchasers via truck transport or pipeline. We do not transport, refine or process the oil we produce. We sell our produced oil under contracts using market-based pricing, which is adjusted for differentials based upon oil quality.
We sell our natural gas and NGLs under purchase contracts using market-based pricing, which is primarily sold at the lease location.
Principal Customers
We sell our oil, natural gas, and NGLs production to marketers which is transported by truck or pipeline to storage facilities arranged by the marketers. Our marketing of oil and natural gas can be affected by factors beyond our control, the effects of which cannot be accurately predicted.
For 2024, 78% of revenues from oil, natural gas, and NGLs sales were to four customers. For 2023, 70% of revenues from oil, natural gas, and NGLs sales were to four customers. No other purchaser accounted for more than 10% of our total revenues during the respective periods. While the loss of these purchasers may result in a temporary interruption in sales of, or a lower price for, our production, we believe that the loss of these purchasers would not have a material adverse effect on our operations, as there are alternative purchasers in our producing regions.
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Competition
The oil and natural gas industry in the areas in which we operate is highly competitive. We encounter strong competition from numerous parties, ranging generally from small independent producers to major integrated companies. We primarily encounter significant competition in acquiring properties. At higher commodity prices, we also face competition in contracting for oil field services, rigs, pressure pumping and workover equipment, and securing trained personnel. Many of these competitors have financial, technical and personnel resources substantially larger than ours. As a result, our competitors may be able to pay more for desirable properties, or to evaluate, bid for and purchase a greater number of properties or prospects than our financial or personnel resources will permit.
In addition to competition for drilling, pressure pumping and workover equipment, we are also affected by the availability of related equipment and materials. The oil and natural gas industry periodically experiences shortages of drilling and workover rigs, equipment, pipe, materials, and personnel, which can delay workover and exploration activities and cause significant price increases. We are unable to predict the timing or duration of any such shortages.
Seasonality of Business
Weather conditions often affect the demand for, and prices of, natural gas and can also delay oil and natural gas production. Demand for natural gas is traditionally higher in the winter, resulting in higher natural gas prices during the first and fourth quarters. Due to these seasonal fluctuations, results of operations for individual quarterly periods may not be indicative of the results realized on an annual basis.
Markets and Price Volatility
The market price of oil and natural gas is volatile, subject to speculative movement and depends upon numerous factors beyond our control, including expectations regarding inflation, global and regional demand, political and economic conditions and production costs. Future profitability, if any, will depend substantially upon the prevailing prices for oil and natural gas. If the market price for oil and natural gas remains depressed in the future, it could have a material adverse effect on our ability to raise the additional capital necessary to finance operations. Lower oil and natural gas prices may also reduce the amount of oil and natural gas, if any, that can be produced economically from our properties. We anticipate that the prices of oil and natural gas will fluctuate in the near future.
Title to Properties
Our title to properties are subject to royalty, overriding royalty, carried, net profits, working and other similar interests and contractual arrangements customary in the oil and natural gas industry, to liens for current taxes not yet due and to other encumbrances. As is customary in the industry in the case of undeveloped properties, only cursory investigation of record title is made at the time of acquisition. Drilling title opinions are usually prepared before commencement of drilling operations. We believe we have satisfactory title to substantially all of our active properties in accordance with standards generally accepted in the natural gas and oil industry. Nevertheless, we are involved in title disputes from time to time that may result in litigation.
Regulation
The oil and natural gas industry is subject to extensive federal, state and local laws and regulations governing the production, transportation and sale of hydrocarbons as well as the taxation of income resulting therefrom. Legislation affecting the oil and natural gas industry is constantly changing. Numerous federal and state departments and agencies have issued rules and regulations applicable to the oil and natural gas industry. In general, these rules and regulations regulate, among other things, the extent to which acreage may be acquired or relinquished; spacing of wells; measures required for preventing waste of oil and natural gas resources; and, in some cases, rates of production. The heavy and increasing regulatory burdens on the oil and natural gas industry increase our cost of doing business and, consequently, affect profitability.
The Comprehensive Environmental, Response, Compensation, and Liability Act (“CERCLA”), also known as the Superfund law, and comparable state statutes impose strict, joint and several liabilities on owners and operators of sites and on persons who disposed of or arranged for the disposal of “hazardous substances” found at such sites. These persons include the owner or operator of the site where the release occurred, persons who disposed or arranged for the disposal of hazardous substances at the site, and any person who accepted hazardous substances for transportation to the site. CERCLA authorizes the EPA, state environmental agencies, and in some cases third parties, to take actions in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. It is not uncommon for the neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment. Although CERCLA currently excludes petroleum from its definition of “hazardous substance,” state laws affecting our operations may impose clean-up liability relating to petroleum and petroleum related products.
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Our oil and natural gas operations are also subject to numerous federal, state and local laws and regulations relating to environmental protection. These laws govern, among other things, the amounts and types of substances and materials that may be released into the environment, the issuance of permits in connection with exploration, drilling and production activities, the reclamation and abandonment of wells and facility sites and the remediation of contaminated sites. These laws and regulations may impose substantial liabilities if we fail to comply or if any contamination results from our operations.
Various state governments and regional organizations comprising state governments have enacted legislation and promulgated rules restricting GHG emissions or promoting the use of renewable energy, and additional such measures are frequently under consideration. Although it is not possible at this time to estimate how potential future requirements addressing GHG emissions would impact operations on the Company properties and revenue, either directly or indirectly, any future federal, state or local laws or implementing regulations that may be adopted to address GHG emissions could require the operators of our properties to incur new or increased costs to obtain permits, operate and maintain equipment and facilities, install new emission controls, acquire allowances to authorize GHG emissions, pay taxes related to GHG emissions or administer a GHG emissions program. Regulation of GHGs could also result in a reduction in demand for and production of oil and natural gas. Additionally, to the extent that unfavorable weather conditions are exacerbated by global climate change or otherwise, the Company properties may be adversely affected to a greater degree than previously experienced.
Our sales of crude oil are affected by the availability, terms, and cost of transportation. The transportation of oil in common carrier pipelines is also subject to rate regulation. The Federal Energy Regulatory Commission (“FERC”), regulates interstate oil pipeline transportation rates under the Interstate Commerce Act. Intrastate oil pipeline transportation rates are subject to regulation by state regulatory commissions. The basis for intrastate oil pipeline regulation, and the degree of regulatory oversight and scrutiny given to intrastate oil pipeline rates, varies from state to state. Insofar as effective interstate and intrastate rates are equally applicable to all comparable shippers, we believe that the regulation of oil transportation rates will not affect our operations in any way that is of material difference from those of our competitors. Further, interstate and intrastate common carrier oil pipelines must provide service on a non-discriminatory basis. Under this open access standard, common carriers must offer service to all shippers requesting service on the same terms and under the same rates. When oil pipelines operate at full capacity, access is governed by pro-rationing provisions set forth in the pipelines’ published tariffs. Accordingly, we believe that access to oil pipeline transportation services generally will be available to us to the same extent as to our competitors.
Employees
At December 31, 2024, we had 63 full-time employees, not including contract personnel and outsourced service providers. Our team is broadly experienced in oil and natural gas operations and follows a strategy of outsourcing most accounting, human resources, and other non-core functions.
Office Locations
Our corporate headquarters are at 2200 South Utica Place, Suite 150, Tulsa, Oklahoma, with field offices in North Dakota, Texas, and New Mexico.
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ITEM 1A. RISK FACTORS.
Our operations are subject to various risks and uncertainties in the ordinary course of business. The following summarizes significant risks and uncertainties that may adversely affect our operations or financial position. Risks and uncertainties discussed below are not a comprehensive listing of those faced by us. Additional risks not presently known or that are deemed immaterial may also affect us. Readers should carefully consider the risk factors included below and other information included and incorporated by reference into this Annual Report on Form 10-K.
Reserves
The Standardized Measure of estimated reserves may not be accurate estimates of the current fair value of estimated proved oil and natural gas reserves.
Standardized Measure is a reporting convention that provides a common basis for comparing oil and natural gas companies subject to the rules and regulations of the SEC. This measure requires the use of operating and development costs prevailing as of the date of computation. Consequently, it will not reflect the prices ordinarily received or that will be received for oil and natural gas production because of varying market conditions, nor may they reflect the actual costs that will be required to produce or develop the oil and natural gas properties. Accordingly, estimates included in this report of future net cash flows may be materially different from the future net cash flows that are ultimately received. In addition, the 10 percent discount factor, which is required by the rules and regulations of the SEC to be used in calculating discounted future net cash flows for reporting purposes, may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with us or the oil and natural gas industry in general.
Therefore, the Standardized Measure included in this report should not be construed as an accurate estimate of the current market value of our proved reserves.
Estimates of proved reserves and future net cash flows are not precise. The actual quantities of our proved reserves and future net cash flows may prove to be lower than estimated.
Numerous uncertainties exist in estimating quantities of proved reserves and future net cash flows therefrom. Estimates of proved reserves and related future net cash flows are based on various assumptions, which may ultimately prove to be inaccurate. Petroleum engineering is a subjective process of estimating accumulations of oil and natural gas that cannot be measured in an exact manner. Estimates of economically recoverable oil and natural gas reserves and of future net cash flows depend upon a number of variable factors and assumptions, including the following:
| · | historical production from the area compared with production from other producing areas; |
| · | the assumed effects of regulations by governmental agencies; |
| · | the quality, quantity and interpretation of available relevant data; |
| · | assumptions concerning future commodity prices; and |
| · | assumptions concerning future operating costs, severance and ad valorem taxes, development costs and workover costs including remediation. |
Because all reserve estimates are to some degree subjective, each of the following items, or other items not identified below, may differ materially from those assumed in estimating reserves:
| · | the quantities of oil and natural gas that are ultimately recovered; |
| · | the production and operating costs incurred; |
| · | the amount and timing of future development expenditures; and |
| · | future commodity prices. |
Furthermore, different reserve engineers may make different estimates of reserves and cash flows based on the same data. Our actual production, revenues and expenditures with respect to reserves will likely be different from estimates and the differences may be material.
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As required by the SEC, the estimated discounted future net cash flows from proved reserves are based on the average previous twelve months first-of-month prices preceding the date of the estimate and costs as of the date of the estimate, while actual future prices and costs may be materially higher or lower. Actual future net cash flows also will be affected by factors such as:
| · | the amount and timing of actual production; |
| · | levels of future capital spending; |
| · | increases or decreases in the supply of or demand for oil, natural gas, and NGLs; and |
| · | changes in governmental regulations or taxation. |
Accordingly, estimates included in this report of future net cash flows may be materially different from the future net cash flows that are ultimately received. Therefore, the estimates of discounted future net cash flows in this report should not be construed as accurate estimates of the current market value of our proved reserves.
Unless reserves are replaced, production and estimated reserves will decline, which may adversely affect our financial condition, results of operations and/or cash flows.
Producing oil and natural gas reservoirs are generally characterized by declining production rates that may vary depending upon reservoir characteristics and other factors. Estimates of the decline rate of an oil or natural gas well are inherently imprecise and may be less precise with respect to new or emerging oil and natural gas formations with limited production histories than for more developed formations with established production histories. Estimated future oil and natural gas reserves and production and, therefore, cash flows and results of operations are highly dependent upon our success in efficiently developing and exploiting current properties and economically finding or acquiring additional recoverable reserves. We may not be able to develop, find or acquire additional reserves to replace our current and future production at acceptable costs. If we are unable to replace our current and future production, cash flows and the value of reserves may decrease, adversely affecting our business, financial condition and results of operations.
New technologies may cause our exploration and development methods to become obsolete, causing an adverse effect on our production.
Our industry is subject to rapid and significant technological advancements, including the introduction of new products and services using new technologies. As competitors use or develop new technologies, we may be at a competitive disadvantage, and competitive pressures may force us to implement new technologies at a substantial cost. In addition, our competitors may have greater financial, technical, and personnel resources that allow them to enjoy technological advantages and may allow them to implement new technologies before we can. We cannot be sure that we can implement technologies timely or at an acceptable cost. One or more technologies we use or that we may implement may become obsolete or may not work as we expected, and we may be hurt financially and operationally as a result.
Financing
We have indebtedness and may incur substantially more debt. Higher levels of indebtedness make us more vulnerable to economic downturns and adverse business developments.
Our total indebtedness at December 31, 2024, was $11.3 million. At December 31, 2024, commitments from a financial institution under a Revolving Credit Facility (the “Credit Facility”) with Empire North Dakota and Empire NDA were approximately $19.8 million, of which approximately $8.7 million was unused and approximately $11.1 million was outstanding. Management continues to review existing indebtedness, and may seek to repay, refinance, repurchase, redeem, exchange or otherwise terminate existing indebtedness. If we do seek to refinance existing indebtedness, there can be no guarantee that we would be able to execute the refinancing on favorable terms or at all.
As a result of indebtedness, we use a portion of our cash flow to pay interest, which reduces the amount available to fund operations and other business activities and could limit flexibility in planning for or reacting to changes in the business and the industry in which we operate. Indebtedness under the Credit Facility is at a variable interest rate, and so a rise in interest rates will generate greater interest expense.
We may incur substantially more debt in the future. The Credit Facility contains restrictions on the incurrence of additional indebtedness.
Increases in the level of indebtedness could have adverse effects on our financial condition and results of operations, including:
| · | imposing additional cash requirements on us in order to support interest payments, which reduces the amount we have available to fund our operations and other business activities; |
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| · | increasing the risk that we may default on our debt obligations; | |
| · | increasing our vulnerability to adverse changes in general economic and industry conditions, economic downturns and adverse developments in our business; |
| · | limiting our ability to sell assets, engage in strategic transactions or obtain additional financing for working capital, capital expenditures, general corporate and other purposes; |
| · | limiting our flexibility in planning for or reacting to changes in our business and the industry in which we operate; and |
| · | increasing our exposure to a rise in interest rates, which will generate greater interest expense. |
Our ability to meet our debt obligations and reduce our level of indebtedness depends on future performance, which is affected by general economic conditions and financial, business and other factors, many of which are outside of the scope of management’s control.
Our business requires substantial capital expenditures. Management may be unable to obtain needed capital or financing on satisfactory terms or at all, which could lead to a decline in oil and natural gas reserves.
The oil and natural gas industry is capital intensive. Management makes and expects to continue to make substantial capital expenditures for the acquisition and development of reserves. We intend to finance future capital expenditures through cash flow from operations, incurring additional indebtedness, or capital raises. However, cash flow from operations and access to capital are subject to a number of variables, including:
| · | the volume of oil, natural gas, and NGLs we are able to produce from existing wells; |
| · | ability to transport oil and natural gas to market; |
| · | the prices at which commodities are sold; |
| · | the costs of producing oil and natural gas; |
| · | global and domestic demand for oil and natural gas; |
| · | global credit and securities markets; |
| · | the ability and willingness of lenders and investors to provide capital and the cost of the capital; |
| · | ability to acquire, locate and produce new reserves; |
| · | the impact of potential changes in our credit ratings; and |
| · | proved reserves. |
We may not generate expected cash flows and obtain the capital necessary to sustain our operations at current or anticipated levels. A decline in cash flow from operations or our financing needs may require management to revise our capital program or alter or increase capitalization substantially through the issuance of debt or equity securities. The issuance of additional equity securities could have a dilutive effect on the value of our common stock. Additional borrowings under the Credit Facility or the issuance of additional debt securities will require that a greater portion of cash flow from operations be used for the payment of interest and principal on debt, thereby reducing our ability to use cash flow to fund working capital, capital expenditures and acquisitions. Additional financing also may not be available on acceptable terms or at all. In the event additional capital resources are unavailable, management may curtail activities or be forced to sell some assets on an untimely or unfavorable basis.
The loss or unavailability of capital provided by our two largest stockholders could have a material adverse effect on our business.
Our two largest stockholders, Energy Evolution Master Fund, Ltd. (“Energy Evolution”) and Phil Mulacek, have been a significant source of capital for our acquisitions of oil and natural gas properties and the development of our oil and natural gas reserves. We have been dependent on this capital to fund our growth plans, including our current drilling programs. The loss of this capital could have a material adverse effect on our business, especially our growth plans.
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If we are unable to comply with the covenants in our agreements governing our indebtedness, including the Credit Facility, there could be a default under the terms of such agreements, which could result in an acceleration of payment of funds that we have borrowed.
Our ability to meet our debt obligations and other expenses will depend on our future performance, which will be affected by financial, business, economic, regulatory and other factors, many of which management is unable to control. If our cash flow is not sufficient to service our debt, we may be required to refinance debt, sell assets or sell additional equity on terms that we may not find attractive if it may be done at all. If we are unable to generate sufficient cash flow and are otherwise unable to obtain funds necessary to meet required payments of principal, premium, if any, and interest, if any, on our indebtedness, or if we otherwise fail to comply with the various covenants, including financial and operating covenants, in the agreements governing our indebtedness, including the Credit Facility, we could be in default under the terms of the agreements governing such indebtedness. In the event of such default:
| · | the holders of such indebtedness could elect to declare all the funds borrowed thereunder to be due and payable, together with accrued and unpaid interest; |
| · | the lenders could elect to terminate their commitments thereunder and cease making further loans; and |
| · | we could be forced into bankruptcy or liquidation. |
If our operating performance declines, we may need to obtain waivers under the Credit Facility, and have done so in the past, to avoid being in default. If we breach our covenants and cannot obtain a waiver from the required lender, we would be in default and the lender could exercise its rights, as described above, and we could be forced into bankruptcy or liquidation.
A negative shift in stakeholder sentiment towards the oil and natural gas industry and increased attention to ESG matters and conservation matters could adversely affect our ability to raise equity and debt capital.
Much of the investor community has developed negative sentiment towards investing in our industry over the past few years. Recent equity returns in the sector versus other industry sectors have led to lower oil and gas representation in certain key equity market indices. Some investors, including certain public and private fund management firms, pension funds, university endowments and family foundations, have stated policies to reduce or eliminate their investments in the oil and natural gas sector based on environmental, social and governance considerations. Certain other stakeholders have pressured private equity firms and commercial and investment banks to stop funding oil and gas projects. Such developments have resulted and could continue to result in downward pressure on the stock prices of oil and natural gas companies, including ours. This may also result in a reduction of available capital funding for potential development projects, further impacting our future financial results.
Increasing attention to climate change, societal expectations on companies to address climate change, investor and societal expectations regarding voluntary ESG disclosures, and consumer demand for alternative forms of energy may result in increased costs, reduced demand for our products, reduced profits, increased investigations and litigation, and negative impacts on our stock price and access to capital markets. Increasing attention to climate change and environmental conservation, for example, may result in demand shifts for oil and natural gas products and additional governmental investigations and private litigation against us or our operators. To the extent that societal pressures or political or other factors are involved, it is possible that such liability could be imposed without regard to our causation of or contribution to the asserted damage, or to other mitigating factors.
Moreover, while we may create and publish voluntary disclosures regarding ESG matters from time to time, many of the statements in those voluntary disclosures are based on hypothetical expectations and assumptions that may or may not be representative of current or actual risks or events or forecasts of expected risks or events, including the costs associated therewith. Such expectations and assumptions are necessarily uncertain and may be prone to error or subject to misinterpretation given the long timelines involved and the lack of an established single approach to identifying, measuring and reporting on many ESG matters.
In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Currently, there are no universal standards for such scores or ratings, but the importance of sustainability evaluations is becoming more broadly accepted by investors and stockholders. Such ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings and recent activism directed at shifting funding away from companies with energy-related assets could lead to increased negative investor sentiment toward us and our industry and to the diversion of investment to other industries, which could have a negative impact on our access to and costs of capital. Also, institutional lenders may decide not to provide funding for fossil fuel energy companies based on climate change related concerns, which could affect our access to capital for potential growth projects.
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General Operations
The oil and natural gas industry is highly competitive, and our size may put us at a disadvantage in competing for resources.
The oil and natural gas industry is highly competitive where our properties and operations are concentrated. We compete with major integrated and larger independent oil and natural gas companies in seeking to acquire desirable oil and natural gas properties and leases and for the equipment and services required to develop and operate properties. Many of our competitors have financial and other resources that are substantially greater than ours, which makes acquisitions of acreage or producing properties at economic prices difficult. Significant competition also exists in attracting and retaining technical personnel, including geologists, geophysicists, engineers, landmen and other specialists, as well as financial and administrative personnel. Hence, we may be at a competitive disadvantage to companies with larger financial resources than ours.
A substantial or extended decline in oil and natural gas prices may adversely affect our business, financial condition or results of operations and our ability to meet our capital expenditure obligations and financial commitments.
The price we receive for our oil and natural gas production heavily influences our revenue, profitability, access to capital and future rate of growth. Oil and natural gas are commodities and, therefore, their prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. Historically, the markets for oil and natural gas have been volatile. These markets will likely continue to be volatile in the future. The prices we receive for our production, and the levels of our production, depend on numerous factors beyond our control. These factors include, but are not limited to, the following:
| · | changes in global supply and demand for oil and natural gas, which could be negatively affected by concerns about public health crises, pandemics and epidemics, such as the COVID-19 pandemic; |
| · | the price and quantity of imports of foreign oil and natural gas; |
| · | political conditions, including trade or other economic sanctions, armed conflict in Ukraine and the Middle East, the price cap on Russian oil and embargoes, in or affecting other oil-producing activity; |
| · | the level of global oil and natural gas exploration and production activity; |
| · | the level of global oil and natural gas inventories; |
| · | weather conditions, including extreme climatic events; |
| · | technological advances affecting energy consumption; and |
| · | the price and availability of alternative fuels. |
Lower oil and natural gas prices may not only decrease our revenues on a per unit basis but also may reduce the amount of oil and natural gas that we can produce economically. Lower prices also negatively impact the value of our proved reserves. Volatility in the price of oil could force us, as well as other operators, to re-evaluate our current capital expenditure budget and make changes accordingly that we believe are in the best interest of us and our stockholders. A substantial or extended decline in oil or natural gas prices may materially and adversely affect our future business, financial condition, results of operations, liquidity or ability to finance planned capital expenditures.
Our producing properties and proved reserves are concentrated in New Mexico, North Dakota, Montana, Texas, and Louisiana, making us vulnerable to risks associated with operating in limited major geographic areas.
Our producing properties are geographically concentrated in New Mexico, North Dakota, Montana, Texas, and Louisiana. At December 31, 2024, all of our total estimated proved reserves were attributable to properties located in these areas. As a result of this concentration, we are exposed to the impact of regional supply and demand factors, delays or interruptions of production from wells in these areas caused by governmental regulation, processing or transportation capacity constraints, market limitations, severe weather events, water shortages or other drought related conditions or interruption of the processing or transportation of oil or natural gas.
This concentration of assets exposes us to additional risks, such as changes in field-wide rules and regulations that could cause us to permanently or temporarily shut-in all of our wells within a field.
A significant portion of our oil, natural gas, and NGLs sales are concentrated in only a few purchasers, which increases our exposure to substantial sales interruptions.
For the year ended December 31, 2024, the Company sold 78% of its oil, natural gas, and NGLs revenues to four customers. No other customer made up more than 10%. As a result of this concentration, we are exposed to the impact of our sales if one of these customers fails to meet their obligations or ceases its relationship with the Company. The loss in revenues may result in a disruption in the Company’s cash flows limiting the ability to meet its obligations or investing in capital projects.
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Our insurance policies may not adequately protect us against certain unforeseen risks.
In accordance with customary industry practice, we maintain insurance against some, but not all, of the risks described in this report. There can be no assurance that any insurance will be adequate to cover our losses or liabilities. We cannot predict the continued availability of insurance, or its availability at premium levels that justify its purchase.
Hedging transactions may expose us to risk of financial loss or limit participation in commodity price increases and involve other risks.
While intended to reduce the effects of volatile oil and natural gas prices, derivative contracts designed as hedges expose us to risk of financial loss in some circumstances, including when there is a change in the expected differential between the underlying price in the derivative contract and actual prices received, or when the counterparty to the derivative contract defaults on its contractual obligations. It is also possible that sales volumes fall below the hedged volumes leaving a portion of our position uncovered.
Alternatively, to the extent that we engage in price risk management activities to protect ourselves from commodity price declines, we may be prevented from fully realizing the benefits of commodity price increases above the prices established by our derivative contracts. Moreover, many of our contract counterparties have become subject to increasing governmental oversight and regulations in recent years, which could adversely affect the cost and availability of our hedging arrangements.
We are subject to various environmental risks, and governmental regulation relating to environmental matters.
We are subject to a variety of federal, state and local governmental laws and regulations related to the storage, use, discharge and disposal of toxic, volatile or otherwise hazardous materials. These regulations subject us to increased operating costs and potential liability associated with the use and disposal of hazardous materials. Although these laws and regulations have not had a material adverse effect on our financial condition or results of operations, there can be no assurance that we will not be required to make material expenditures in the future. Moreover, we anticipate that such laws and regulations will become increasingly stringent in the future, which could lead to material costs for environmental compliance and remediation by us. Any failure by us to obtain required permits for, control the use of, or adequately restrict the discharge of hazardous substances under present or future regulations could subject us to substantial liability or could cause our operations to be suspended. Such liability or suspension of operations could have a material adverse effect on our business, financial condition and results of operations.
Our activities are subject to extensive governmental regulation. Oil and natural gas operations are subject to various federal, state and local governmental regulations that may be changed from time to time in response to economic or political conditions. From time to time, regulatory agencies have imposed price controls and limitations on production in order to conserve supplies of oil and natural gas. In addition, the production, handling, storage, transportation and disposal of oil and natural gas, by-products thereof and other substances and materials produced or used in connection with oil and natural gas operations are subject to regulation under federal, state and local laws and regulations primarily relating to protection of human health and the environment. To date, expenditures related to complying with these laws and for remediation of existing environmental contamination have not been significant in relation to our operations. There can be no assurance that the trend of more expansive and stricter environmental legislation and regulations will not continue.
If forecasted prices for oil, natural gas, and NGLs decrease, we may be required to take significant future write-downs of the financial carrying values of our properties in the future.
Accounting rules require that we periodically review the carrying value of our proved and unproved properties for possible impairment. Based on prevailing commodity prices and specific market factors and circumstances at the time of prospective impairment reviews, and the continuing evaluation of development plans, production data, economics and other factors, we may be required to significantly write-down the financial carrying value of our oil and natural gas properties, which constitutes a non-cash charge to earnings. We may incur impairment charges in the future, which could have a material adverse effect on our results of operations for the periods in which such charges are recorded.
A write-down could occur when oil and natural gas prices are low or if we have substantial downward adjustments to our estimated proved oil and natural gas reserves, or if operating costs or development costs increase over prior estimates.
The capitalized costs of our oil and natural gas properties, on a field-by-field basis, may exceed the estimated future net cash flows of that field. If so, we would record impairment charges to reduce the capitalized costs of such field to our estimate of the field’s fair market value. Unproved properties are evaluated at the lower of cost or fair market value. These types of charges will reduce our earnings and stockholders’ equity and could adversely affect our stock price.
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We periodically assess our properties for impairment based on future estimates of proved and unproved reserves, oil and natural gas prices, production rates and operating, development and reclamation costs based on operating budget forecasts. Once incurred, an impairment charge cannot be reversed at a later date even if price increases of oil and/or natural gas occur and in the event of increases in the quantity of our estimated proved reserves.
If oil, natural gas and NGLs prices fall below current levels for an extended period of time and all other factors remain equal, we may incur impairment charges in the future. Such charges could have a material adverse effect on our results of operations for the periods in which they are recorded.
Properties we acquire may not produce as projected and we may be unable to determine reserve potential, identify liabilities associated with the properties that we acquire or obtain protection from sellers against such liabilities.
Acquiring oil and natural gas properties requires us to assess reservoir and infrastructure characteristics, including recoverable reserves, development and operating costs and potential environmental and other liabilities. Such assessments are inexact and inherently uncertain and include properties with which we do not have a long operational history. In connection with the assessments, we perform a review of the subject properties, but such a review will not reveal all existing or potential problems. In the course of our due diligence, we may not inspect every well or pipeline. We cannot necessarily observe structural and environmental problems, such as pipe corrosion, when an inspection is made. We may not be able to obtain contractual indemnities from the seller for liabilities created prior to our purchase of a property. We may be required to assume the risk of the physical condition of properties in addition to the risk that they may not perform in accordance with our expectations. If properties we acquire do not produce as projected or have liabilities we were unable to identify, we could experience a decline in our reserves and production, which could adversely affect our business, financial condition and results of operations.
Many of our properties are in areas that may have been partially depleted or drained by offset wells and certain of our wells may be adversely affected by actions we or other operators may take when drilling, completing, or operating wells that we or they own.
Many of our properties are in reservoirs that may have already been partially depleted or drained by earlier offset drilling. The owners of leasehold interests adjoining any of our properties could take actions, such as drilling and completing additional wells, which could adversely affect our operations. When a new well is completed and produced, the pressure differential in the vicinity of the well causes the migration of reservoir fluids toward the new wellbore and potentially away from existing wellbores. As a result, the drilling and production of these potential locations by us or other operators could cause depletion of our proved reserves and may inhibit our ability to further develop our proved reserves. In addition, completion operations and other activities, including water disposal activities, conducted on adjacent or nearby wells could cause production from our wells to be shut in for indefinite periods of time, could result in increased lease operating expenses and could adversely affect the production and reserves from our wells after they re-commence production. We have no control over the operations or activities of offsetting operators.
Acquisitions involve a number of risks, including the risk that we will discover unanticipated liabilities or other problems associated with the acquired business or property.
In assessing potential acquisitions, we consider information available in the public domain and information provided by the seller. In the event publicly available data is limited, then, by necessity, we may rely to a large extent on information that may only be available from the seller, particularly with respect to drilling and completion costs and practices, geological, geophysical and petrophysical data, detailed production data on existing wells, and other technical and cost data not available in the public domain. Accordingly, the review and evaluation of businesses or properties to be acquired may not uncover all existing or relevant data, obligations or actual or contingent liabilities that could adversely impact any business or property to be acquired and, hence, could adversely affect us as a result of the acquisition. These issues may be material and could include, among other things, unexpected environmental liabilities, title defects, unpaid royalties, taxes or other liabilities.
The success of any acquisition that we complete will depend on a variety of factors, including our ability to accurately assess the reserves associated with the acquired properties, assumptions related to future oil and natural gas prices and operating costs, potential environmental and other liabilities and other factors. These assessments are often inexact and subjective. As a result, we may not recover the purchase price of a property from the sale of production from the property or recognize an acceptable return from such sales or operations.
Our ability to achieve the benefits that we expect from an acquisition will also depend on our ability to efficiently integrate the acquired operations. Management may be required to dedicate significant time and effort to the integration process, which could divert its attention from other business opportunities and concerns. The challenges involved in the integration process may include retaining key employees and maintaining employee morale, addressing differences in business cultures, processes and systems and developing internal expertise regarding acquired properties.
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Our operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which we may conduct oil, natural gas, and NGLs exploration and production activities, and reduce demand for the oil, natural gas, and NGLs we produce.
In the United States, no comprehensive climate change legislation has been implemented at the federal level. However, following the U.S. Supreme Court finding that GHG emissions constitute a pollutant under the Clean Air Act, the EPA has adopted regulations that, among other things, establish construction and operating permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources in the United States, impose new standards reducing methane emissions from oil and gas operations through limitations on venting and flaring and the implementation of enhanced emission leak detection and repair requirements, and together with the United States Department of Transportation, implement GHG emissions limits on vehicles manufactured for operation in the United States. The federal regulation of methane emissions from oil and natural gas facilities has been subject to considerable attention in recent years. In December 2023, the EPA finalized new and updated rules for both new and existing sources. The final rules make existing regulations more stringent, expand the scope of source types covered by the rules and require states to develop plans to reduce methane and volatile organic compound emissions from existing sources. These new rules have been subject to legal challenges. The Trump Administration may seek to revise or repeal these rules. As a result, we cannot predict the scope of any final methane regulatory requirements or the cost to comply with such requirements. However, given the long-term trend toward increasing regulation, future federal GHG regulations of the oil and natural gas industry remain a significant possibility.
Governmental, scientific, and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political risks in the United States, including climate change related pledges made by certain candidates elected to public office. Former President Biden issued several executive orders focused on addressing climate change, including items that may impact costs to produce, or demand for, oil and gas. There are also increasing financial risks for fossil fuel producers as shareholders currently invested in fossil-fuel energy companies may elect in the future to shift some or all of their investments into other sectors. Institutional lenders who provide financing to fossil-fuel energy companies also have become more attentive to sustainable lending practices and some of them may elect not to provide funding for fossil fuel energy companies. There is also a risk that financial institutions will be pressured or required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. Former President Biden signed an executive order calling for the development of a “climate finance plan” and, separately, the Federal Reserve has joined the Network for Greening the Financial System (“NGFS”), a consortium of financial regulators focused on addressing climate-related risks in the financial sector. Limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities.
Policy makers have also advocated for expanding existing, or creating new, reporting and disclosure requirements regarding GHG emissions and other climate-related matters. For example, the EPA adopted amendments in May 2024 to its GHG Reporting Program, which, among other things, added well blowouts and other abnormal events as new categories of sources for GHG emissions reporting. In addition, the SEC finalized rules in March 2024 that require public companies to include extensive climate-related disclosures in their SEC filings, such as new disclosures on (i) material Scope 1 and 2 GHG emissions, including an independent assurance report, which currently would not apply to Empire given its size, and (ii) financial statement information regarding the effects of severe weather events and other natural conditions. In April 2024, the SEC stayed the effectiveness of these rules pending the completion of a judicial review of certain legal challenges. While we are still awaiting resolution of the review of the SEC climate change rules, we are continuing to assess its potential impact and expect heightened disclosure requirements given that reporting frameworks on GHG emissions and other climate-related metrics are still maturing and often require the use of numerous assumptions and judgments.
The adoption and implementation of new or more stringent international, federal or state legislation, regulations or other regulatory initiatives that impose more stringent standards for GHG emissions from the oil and natural gas sector or otherwise restrict the areas in which this sector may produce oil and natural gas or generate GHG emissions could result in increased costs of compliance or costs of consuming, and thereby reduce demand for, oil and natural gas. Additionally, political, litigation and financial risks may result in us restricting or cancelling production activities, incurring liability for infrastructure damages as a result of climatic changes, or having an impaired ability to continue to operate in an economic manner. One or more of these developments could have a material adverse effect on our business, financial condition and results of operations.
In addition to regulatory risk, other market and social initiatives relating to climate change present risks for our business. For example, in an effort to promote a lower-carbon economy, there are various public and private initiatives subsidizing or otherwise encouraging the development and adoption of alternative energy sources and technologies, including by mandating the use of specific fuels or technologies. These initiatives may reduce the competitiveness of carbon-based fuels, such as oil and gas. Moreover, an increasing number of financial institutions, funds and other sources of capital have restricted or eliminated their investment in oil and natural gas activities due to their concern regarding climate change. Such restrictions in capital could decrease the value of our business and make it more difficult to fund our operations. In addition, governmental entities and other plaintiffs have brought, and may continue to bring, claims against us and other oil and gas companies for purported damages caused by the alleged effects of climate change. The increasing attention to climate change may result in further claims or investigations against us, and heightened societal or political pressures may increase the possibility that liability could be imposed on us in such matters without regard to our causation of, or contribution to, the asserted damage or violation, or to other mitigating factors.
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As a final note, climate change could have an effect on the severity of weather (including hurricanes, droughts and floods), sea levels, water availability and quality, and meteorological patterns. If such effects were to occur, our development and production operations have the potential to be adversely affected.
Potential adverse effects could include damage to our facilities from powerful winds, extreme temperatures, or rising waters in low-lying areas, disruption of our production activities either because of climate related damages to our facilities or in our costs of operation potentially arising from such climatic effects, less efficient or non- routine operating practices necessitated by climate effects or increased costs for insurance coverage in the aftermath of such effects. Significant physical effects of climate change could also have an indirect effect on our financing and operations by disrupting the transportation or process-related services provided by midstream companies, service companies or suppliers with whom we have a business relationship. Additionally, changing meteorological conditions, particularly temperature, may result in changes to the amount, timing, or location of demand for energy or the products we produce. We may not be able to recover through insurance some or any of the damages, losses or costs that may result from potential physical effects of climate change. At this time, we have not developed a comprehensive plan to address the legal, economic, social or physical impacts of climate change on our operations.
The marketability of our production is dependent upon gathering systems, transportation facilities and processing facilities that we do not own or control. If these facilities or systems are unavailable, our oil and natural gas production can be interrupted and our revenues reduced.
The marketability of our oil and natural gas production is dependent upon the availability, proximity and capacity of pipelines, natural gas gathering systems, transportation and processing facilities owned by third parties. In general, we will not control these facilities, and our access to them may be limited or denied due to circumstances beyond our control. A significant disruption in the availability of these facilities could adversely impact our ability to deliver to market the hydrocarbons we produce and thereby cause a significant interruption in our operations. In some cases, our ability to deliver to market our hydrocarbons is dependent upon coordination among third parties that own transportation and processing facilities we use, and any inability or unwillingness of those parties to coordinate efficiently could also interrupt our operations. The lack of availability or the lack of capacity on these systems and facilities could result in the curtailment of production or the delay or discontinuance of drilling plans. These are risks for which we generally will not maintain insurance.
We operate or participate in oil and natural gas leases with third-parties who may not be able to fulfill their commitments to our projects.
In some cases, we operate but own less than 100% of the working interest in the oil and natural gas leases on which we conduct operations, and other parties own the remaining portion of the working interest. Financial risks are inherent in any operation where the cost of drilling, equipping, completing and operating wells is shared by more than one person. We could be held liable for joint activity obligations of other working interest owners, such as nonpayment of costs and liabilities arising from the actions of other working interest owners. In addition, declines in oil, natural gas and NGLs prices may increase the likelihood that some of these working interest owners, particularly those that are smaller and less established, are not able to fulfill their joint activity obligations. A partner may be unable or unwilling to pay its share of project costs, and, in some cases, a partner may declare bankruptcy. In the event any of our project partners do not pay their share of such costs, we would likely have to pay those costs, and we may be unsuccessful in any efforts to recover these costs from our partners, which could materially adversely affect our financial position.
Because we cannot control activities on properties we do not operate, we cannot directly control the timing of exploration. If we are unable to fund required capital expenditures with respect to non-operated properties, our interests in those properties may be reduced or forfeited.
Our ability to exercise influence over operations and costs for the properties we do not operate is limited. Our dependence on the operators and other working interest owners for these projects and our limited ability to influence operations and associated costs could prevent the realization of our targeted returns on capital with respect to acquisition, exploration and development activities. The success and timing of development, exploitation and exploration activities on properties operated by others depend upon a number of factors that may be outside our control, including but not limited to the timing and amount of capital expenditures; the operator’s expertise and financial resources; the approval of other participants in drilling wells; and the selection of technology.
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Where we are not the majority owner or operator of a particular oil and natural gas project, we may have no control over the timing or amount of capital expenditure associated with the project. If we are not willing or able to fund required capital expenditures relating to a project when required by the majority owner(s) or operator, our interests in the project may be reduced or forfeited. Also, we could be responsible for plugging and abandonment costs, as well as other liabilities in excess of our proportionate interest in the property.
We could be adversely affected by increased costs of service providers utilized by us.
In accordance with customary industry practice, we have relied and will rely on independent third-party service providers to provide most of the services necessary to operate. The industry has experienced significant price fluctuations for these services during the last year and this trend is expected to continue into the future. These cost uncertainties could, in the future, significantly increase our production costs.
Our ability to use our existing net operating loss carryforwards or other tax attributes could be further limited.
In the event that an entity has an “ownership change” (as defined in Section 382 of the Internal Revenue Code of 1986, as amended (the “Code”)), an entity’s federal net operating loss carryforwards (“NOLs”) generated prior to an ownership change would be subject to annual limitations, which could defer or eliminate our ability to utilize these tax losses against future taxable income. Generally, an “ownership change” occurs if one or more stockholders, each of whom owns 5% or more in value of a corporation’s stock, increase their aggregate percentage ownership by more than 50% over the lowest percentage of stock owned by those stockholders at any time during the preceding three-year period. A full Section 382 analysis was prepared in 2024, and it was determined that our NOLs were subject to limitations under Section 382.
At December 31, 2024, we had approximately $35.8 million of federal NOLs generated in prior years that could offset against future taxable income, however, $2.4 million of the NOLs were limited as of December 31, 2024 due to ownership changes. NOLs created prior to 2018 have a 20-year expiration period and NOLs arising after 2017 have an indefinite life. Additionally, utilization of any NOL depends on many factors, including our ability to generate future taxable income, which cannot be assured. At December 31, 2024, we had a full tax valuation allowance recorded on the NOLs.
In the event that we were to undergo any further “ownership change”, our NOLs generated prior to an ownership change would be subject to further annual limitations, which could defer or eliminate our ability to utilize these tax losses against future taxable income.
Legislation
Climate change legislation, regulations restricting emissions of GHG’s or legal or other action taken by public or private entities related to climate change could result in increased operating costs and reduced demand for the oil and natural gas that we produce.
The threat of climate change continues to attract considerable attention in the United States and around the world. Numerous proposals have been made and could continue to be made at the international, national, regional and state levels of government to monitor and limit existing emissions of GHGs as well as to restrict or eliminate such future emissions. These efforts have included consideration of cap-and-trade programs, carbon taxes, GHG disclosure obligations and regulations that directly limit GHG emissions from certain sources. Moreover, Former President Biden highlighted addressing climate change as a priority of his administration, issued several executive orders related to climate change and recommitted the United States to long-term international goals to reduce emissions, and continues to require the incorporation of climate change considerations into executive agency decision-making. In recent years, Congress has considered legislation to reduce emissions of GHGs, including methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of natural gas. For example, the Inflation Reduction Act of 2022, which appropriates significant federal funding for renewable energy initiatives and, for the first time, imposes a fee on GHG emissions from certain facilities, was signed into law in August 2022. The emissions fee and funding provisions of the law could increase operating costs within the oil and natural gas industry and accelerate the transition away from fossil fuels, which could in turn adversely affect our business and results of operations.
At the international level, the United Nations ("UN") sponsored the "Paris Agreement" requires member states to submit non-binding, individually-determined reduction goals known as Nationally Determined Contributions every five years after 2020. Former President Biden recommitted the United States to the Paris Agreement and, in April 2021, announced a goal of reducing the United States' emissions by 50 to 52% below 2005 levels by 2030. Subsequent UN climate conferences have called for additional action to transition away from fossil fuels or otherwise reduce GHG emissions. Various states and local governments have also publicly committed to furthering the goals of the Paris Agreement. In January 2025, the Trump Administration re-withdrew the United States from the Paris Agreement, and the United States’ participation in future UN climate related efforts is unclear. The full impact of these actions is uncertain at this time, and it is unclear what additional initiatives may be adopted or implemented that may have adverse effects upon our operations.
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The adoption of legislation or regulatory programs to reduce emissions of GHGs could require us to incur increased operating costs, such as costs to purchase and operate emissions control systems, to acquire emissions allowances or to comply with new regulatory or reporting requirements. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, the oil and natural gas we produce. Consequently, legislation and regulatory programs to reduce emissions of GHGs could have an adverse effect on our business, financial condition and results of operations. Reduced demand for the oil and natural gas that we produce could also have the effect of lowering the value of our reserves. It should also be noted that some scientists have concluded that increasing concentrations of GHGs in the earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events. If any such effects were to occur, they could have an adverse effect on our financial condition and results of operations. In addition, there have also been efforts in recent years to influence the investment community, including investment advisors and certain sovereign wealth, pension and endowment funds promoting divestment of fossil fuel equities and pressuring lenders to limit funding to companies engaged in the extraction of fossil fuel reserves. Such environmental activism and initiatives aimed at limiting climate change and reducing air pollution could interfere with our business activities, operations and ability to access capital. Finally, increasing attention to the risks of climate change has resulted in an increased possibility of lawsuits or investigations brought by public and private entities against oil and natural gas companies in connection with their GHG emissions. Should we be targeted by any such litigation or investigations, we may incur liability, which, to the extent that societal pressures or political or other factors are involved, could be imposed without regard to the causation of or contribution to the asserted damage, or to other mitigating factors. The ultimate impact of GHG emissions-related agreements, legislation and measures on our company’s financial performance is highly uncertain because we are unable to predict with certainty, for a multitude of individual jurisdictions, the outcome of political decision-making processes and the variables and tradeoffs that inevitably occur in connection with such processes.
Any change to government regulation or administrative practices may have a negative impact on our ability to operate and our profitability.
Oil and natural gas operations are subject to substantial regulation under federal, state and local laws relating to the exploration for, and the development, upgrading, marketing, pricing, taxation, and transportation of, oil and natural gas and related products and other associated matters. Amendments to current laws and regulations governing operations and activities of oil and natural gas exploration and development operations could have a material adverse impact on our business. In addition, there can be no assurance that income tax laws, royalty regulations and government programs related to our oil and natural gas properties and the oil and natural gas industry generally will not be changed in a manner which may adversely affect our progress or cause delays.
Permits, leases, licenses, and approvals are required from a variety of regulatory authorities at various stages of exploration and development. There can be no assurance that the various government permits, leases, licenses and approvals sought will be granted in respect of our activities or, if granted, will not be cancelled or will be renewed upon expiration. There is no assurance that such permits, leases, licenses, and approvals will not contain terms and provisions which may adversely affect our exploration and development activities.
Other
A cyber incident could result in information theft, data corruption, operational disruption and/or financial loss.
The oil and natural gas industry has become increasingly dependent on digital technologies to conduct day-to-day operations including certain exploration, development and production activities. We are dependent on digital technologies including information systems and related infrastructure, to process and record financial and operating data, communicate with our employees, business partners, and stockholders, analyze 3-D seismic and drilling information, estimate quantities of oil and natural gas reserves as well as other activities related to our business.
As dependence on digital technologies has increased, cyber incidents, including deliberate attacks or unintentional events, have also increased. A cyber-attack could include gaining unauthorized access to digital systems for the purposes of misappropriating assets or sensitive information, corrupting data, causing operational disruption, or result in denial-of-service on websites.
Our technologies, systems, networks, and those of our business partners may become the target of cyber-attacks or information security breaches that could result in the unauthorized release, gathering, monitoring, misuse, loss or destruction of proprietary and other information, or other disruption of our business operations. In addition, certain cyber incidents, such as surveillance, may remain undetected for an extended period of time. In particular, our implementation of various procedures and controls to monitor and mitigate security threats and to increase security for our information, data, facilities and infrastructure may result in increased capital and operating costs. Costs for insurance may also increase as a result of security threats, and some insurance coverage may become more difficult to obtain, if available at all. Moreover, there can be no assurance that such procedures and controls will be sufficient to prevent security breaches from occurring. As cyber threats continue to evolve, we may be required to expend significant additional resources to continue to modify or enhance our protective measures or to investigate and remediate any information security vulnerabilities. A cyber incident involving our information systems and related infrastructure, or that of our business partners, could disrupt our business plans and negatively impact our operations.
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The loss or unavailability of any of our executive officers or other key employees could have a material adverse effect on our business.
We depend greatly on the efforts of our executive officers and other key employees to manage our operations. The loss or unavailability of any of our executive officers or other key employees could have a material adverse effect on our business.
We have had material weaknesses in our internal control over financial reporting in prior fiscal years. Failure to maintain effective internal control over financial reporting could adversely affect our ability to report our financial condition and results of operations accurately and on a timely basis. As a result, our business, operating results and liquidity could be harmed.
As disclosed in our prior annual reports on Form 10-K, we identified a material weakness in internal controls over financial reporting as of December 31, 2022, and 2021. We believe that this material weakness has been successfully remediated.
Our failure to maintain effective internal control over financial reporting could adversely affect our ability to report our financial results on a timely and accurate basis, which could result in a loss of investor confidence in our financial reports or have a material adverse effect on our ability to operate our business or access sources of liquidity. Furthermore, because of the inherent limitations of any system of internal control over financial reporting, including the possibility of human error, the circumvention or overriding of controls and fraud, even effective internal controls may not prevent or detect all misstatements.
We do not expect to declare or pay any dividends in the foreseeable future.
We have not declared or paid any dividends on our common stock. We currently intend to retain future earnings to fund the development and growth of our business, to repay indebtedness and for general corporate purposes, and therefore, do not anticipate paying any cash dividends on our common stock in the foreseeable future.
The price of our common stock may fluctuate significantly, which could negatively affect us and the holders of our common stock.
Our common stock trades on the NYSE American. The trading price of our common stock may fluctuate significantly in response to a number of factors, many of which are beyond our control. Adverse events including changes in production volumes, worldwide demand and prices for crude oil and natural gas, regulatory developments, and changes in any securities analysts’ estimates of our financial performance could negatively impact the market price of our common stock. General market conditions, including the level of, and fluctuations in, the trading prices of stocks generally could also have a similar negative impact. The stock markets regularly experience price and volume volatility that affects many companies’ stock prices without regard to the operating performance of those companies. Volatility of this type may affect the trading price of our common stock.
Provisions of our certificate of incorporation and bylaws and Delaware law may inhibit a takeover, which could limit the price investors might be willing to pay in the future for our common stock.
Provisions in our certificate of incorporation and bylaws may have the effect of delaying or preventing an acquisition of us or a merger in which we are not the surviving company and may otherwise prevent or slow changes in our board of directors and management. In addition, because we are incorporated in Delaware, we are governed by the provisions of Section 203 of the General Corporation Law of the State of Delaware, which provides certain restrictions on business combinations involving interested parties. These provisions could discourage an acquisition of us or other change in control transactions and thereby negatively affect the price that investors might be willing to pay in the future for our common stock.
Holders of our outstanding Series A Voting Preferred Stock have effective control of our board of directors.
We have six shares of Series A Voting Preferred Stock currently issued and outstanding. The Series A Voting Preferred Stock was issued in connection with the strategic investment in us by Energy Evolution. For so long as the Series A Voting Preferred Stock is outstanding, our board of directors will consist of six directors. Three of the directors are designated as the Series A Directors and the three other directors (each, a “common director”) are elected by the holders of common stock and/or any preferred stock (other than the Series A Voting Preferred Stock) granted the right to vote on the common directors. Any Series A Director may be removed with or without cause but only by the affirmative vote of the holders of a majority of the Series A Voting Preferred Stock voting separately and as a single class. The holders of the Series A Voting Preferred Stock have the exclusive right, voting separately and as a single class, to vote on the election, removal and/or replacement of the Series A Directors. Holders of common stock or other preferred stock have no right to vote on the Series A Directors. In addition, in the case of any tie vote or deadlock of the board of directors, our current Chairman of the Board, a Series A Director, has the deciding, tiebreaking vote. Accordingly, the holder(s) of our Series A Voting Preferred Stock have effective control of our board of directors for so long as the voting rights of the Series A Voting Preferred Stock remain in effect.
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Our bylaws provide that the Court of Chancery of the State of Delaware (or if the Court of Chancery does not have jurisdiction, the federal district court for the District of Delaware) will be the exclusive forum for certain legal actions between us and our stockholders. These provisions could increase costs to bring a claim, discourage claims or limit the ability of our stockholders to bring a claim in a judicial forum viewed by the stockholders as more favorable for disputes with us or our directors, officers or employees.
Our bylaws provide that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware (or if the Court of Chancery does not have jurisdiction, the federal district court for the District of Delaware) will be the sole and exclusive forum for (a) any derivative action or proceeding brought on our behalf, (b) any action asserting a claim of breach of a fiduciary duty owed by any director, officer, stockholder, employee or agent to us or our stockholders, (c) any action asserting a claim arising pursuant to any provision of the General Corporation Law of the State of Delaware, our certificate of incorporation or our bylaws, or (d) any action asserting a claim governed by the internal affairs doctrine, in each case subject to the court having personal jurisdiction over the defendants. This exclusive forum provision is intended to apply to claims arising under Delaware state law and is not intended to apply to claims arising under the Securities Act or the Exchange Act. The choice of forum provisions may increase costs to bring a claim, discourage claims or limit a stockholder's ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers or employees, which may discourage such lawsuits against us or our directors, officers and employees. Alternatively, if a court were to find the choice of forum provision contained in our bylaws to be inapplicable or unenforceable in an action, we may incur additional costs associated with resolving such action in other jurisdictions.
The credit risk of our counterparties could adversely affect us.
We enter into a variety of transactions that expose us to counterparty credit risk. For example, we have exposure to financial institutions and insurance companies through our hedging arrangements, our Credit Facility and our insurance policies. Disruptions in the financial markets or otherwise may impact these counterparties and affect their ability to fulfill their existing obligations and their willingness to enter into future transactions with us.
In addition, we are exposed to the risk of financial loss from trade, joint interest billing and other receivables. We sell our oil, gas and NGLs to a variety of purchasers, and, as an operator, we pay expenses and bill our non-operating partners for their respective share of costs. Certain of these counterparties or their successors may experience insolvency, liquidity problems or other issues and may not be able to meet their obligations owed to us, particularly during a depressed or volatile commodity price environment. Any such default may result in us being forced to cover the costs of those obligations and liabilities.
ITEM 1B. UNRESOLVED STAFF COMMENTS.
None.
ITEM 1C. CYBERSECURITY.
The Company continues to implement policies, standards, processes and practices for assessing, identifying, and managing material risks from cybersecurity threats. We employ a variety of tools designed to identify, assess and maintain security measures to meet regulatory requirements, and possess technical personnel to maintain the security of our data and cybersecurity infrastructure. There can be no guarantee that our policies and procedures will be properly followed in every instance or that those policies and procedures will be effective. Our risk factors, which can be found in Item 1A. “Risk Factors,” include further detail about the material cybersecurity risks we face. There can be no assurance that there will not be incidents in the future or that they will not materially affect us, including our business strategy, results of operations, or financial condition.
Risk Management and Strategy Overview
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To protect our IT systems and information from cybersecurity risks, we use and continue to implement various security tools that help prevent, identify, escalate, investigate, resolve, and recover from identified cybersecurity vulnerabilities and incidents in a timely manner. These include monitoring and detection programs, network security measures, firewall monitoring devices and multi-factor authentication which are all overseen by our IT Director, who possesses the necessary expertise to implement the appropriate tools and processes to effectively manage cybersecurity risks. With over 30 years of experience in the oil and natural gas industry, our IT Director has 12 years of cybersecurity experience where he has led several teams introducing cybersecurity initiatives and implementing robust frameworks and response plans against cyber threats.
We are actively assessing the technological risks to our key IT systems and information and are implementing controls to identify and manage cybersecurity risks associated with all third-party service providers. These include, but are not limited to, an understanding of access controls, a records and information management policy, change control procedures, risk and control registry, and configuration standards.
Employee awareness of cybersecurity risks and threats is also an important part of an effective control environment. We periodically communicate to employees about this cybersecurity awareness. We are working on an implementation plan to require each of our employees to complete an annual information security training course, in addition to other training requirements. This should lead to an educated, informed, and prepared workforce, with an awareness of potential cybersecurity threats, how they may occur, and how to report and escalate such matters.
While we have not, as of the date of this Annual Report on Form 10-K, experienced a cybersecurity incident that has materially impacted our business or operations, there can be no guarantee that we will not experience such a threat or incident in the future. A material cybersecurity threat or incident could adversely impact our operations, our sales or financial and administrative functions, or result in the compromise of personal or other confidential information of our employees, customers, or suppliers. For this reason, we maintain cybersecurity liability insurance to provide additional support, expertise, and resources to help ensure the integrity of our cybersecurity processes and to provide a level of financial protection in the event of cybersecurity incident related costs and losses.
Governance
ITEM 2. PROPERTIES.
Information regarding our properties is included in Item 1 above and in our consolidated financial statements, which is incorporated herein by reference.
ITEM 3. LEGAL PROCEEDINGS.
For information regarding legal proceedings, see Note 15 in our consolidated financial statements.
ITEM 4. MINE SAFETY DISCLOSURES.
Not applicable.
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PART II
| ITEM 5. | MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES. |
Market Information
Our common stock is traded on the NYSE American under the symbol "EP".
Stockholders
At March 25, 2025, there were approximately 1,350 stockholders of record of our common stock.
Dividends
We have never paid cash dividends on our common stock. We intend to retain future earnings for use in our business and, therefore, do not anticipate paying cash dividends on our common stock in the foreseeable future. Future payment of dividends will depend upon, but not be limited to, our financial condition, funds available for operations, the amount of anticipated capital and other expenditures, future business prospects and any restrictions imposed by present or future financing arrangements.
Issuer Repurchase of Equity Securities
No private or open market repurchases of common stock were made by us during the fourth quarter of 2024.
Unregistered Sales of Equity Securities
No such sales that have not been previously reported on a Quarterly Report on Form 10-Q or a Current Report on Form 8-K.
| ITEM 6. | RESERVED. |
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
The following discussion and analysis presents management’s perspective of our business, financial condition and overall performance. This information is intended to provide investors with an understanding of our past performance, current financial condition and outlook for the future and should be read in conjunction with the consolidated financial statements and notes to consolidated financial statements, which are included in this Annual Report on Form 10-K in Item 8, Financial Statements and Supplementary Data, and the information set forth in Part I, Item 1A – Risk Factors.
Overview
Our primary business is the optimization and development of oil and gas interests. We have incurred losses from operations in 2024 and 2023. There is no assurance that we will be profitable or obtain funds necessary to finance our future operations.
We seek to increase shareholder value by growing reserves, production, revenues, and cash flow from operating activities by executing our mission to use highly-skilled personnel to thoughtfully and expertly spend capital to realize reserves on producing properties as well as further develop fields.
Management places emphasis on operating cash flow in managing our business, as operating cash flow considers the cash expenses incurred during the period and excludes non-cash expenditures not related directly to our operations.
Inflation
The effect of inflation on the Company has generally been to increase its cost of operations, general and administrative costs and direct costs associated with oil and natural gas production.
Business Strategy
Our business strategy is to obtain long-term growth in reserves and cash flow on a cost-effective basis. Management regularly evaluates potential acquisitions of properties that would enhance current core areas of operation.
Liquidity and Going Concern
The Company has a revolving line of credit agreement with Equity Bank which requires the Company to maintain compliance with certain financial covenants computed on a quarterly and annual basis. As of December 31, 2024, the Company was in compliance with all required covenants and projected to be in compliance with all debt covenants over the next 12 months. However, the Company was in default of its covenants in the third quarter of 2024 but obtained a waiver on November 12, 2024, to alleviate all prior defaults. The Company carried a negative working capital of approximately $8.9 million as of December 31, 2024, an overall decline of approximately $2.6 million from the previous year. Cash on hand also declined approximately $5.5 million during the same period. The overall decline in working capital and cash is primarily driven by the Starbuck Drilling Program in North Dakota which incurred substantial capital spend. Additionally, the Company initiated a return-to-production program in Texas which incurred additional unforeseen operational costs. The additional production from these projects did not fully offset the costs incurred and contributed to the overall negative financial trend. To meet its obligations, the Company increased its revolver commitment to $20.0 million in November 2024 and had two rights offerings in April and November of 2024 which raised approximately $30.5 million of capital, net of transaction costs, to help fund the capital spend projects. Additionally, as a result of increasing its revolver commitment, the Company had approximately $8.7 million remaining unused commitment as of December 31, 2024, which can be used for future obligations. However, the revolver commitment is reduced monthly by $0.25 million commencing on December 31, 2024 (See Note 7), limiting future access to capital. While these debt and equity transactions provided additional funding towards these projects and other obligations, the Company still carried approximately $8.9 million of negative working capital at period end and future expected operating cash flows do not sufficiently meet the Company’s obligations for the next 12 months. Given the negative working capital and insufficient expected operating cash flow there is substantial doubt about the Company’s ability to continue as a going concern.
Empire has committed financial support from Phil Mulacek who owns approximately 21.2% of our common stock outstanding as of December 31, 2024, and Energy Evolution, our largest stockholder who owns approximately 31.9% of our common stock outstanding as of December 31, 2024. Both are related parties of the Company (see Note 14). Mr. Mulacek and Energy Evolution are willing and able to provide these additional funds, if required, for Empire to continue to meet its obligations over the next 12 months. These additional funds may be raised through related party warrants, or a related party note payable that may or may not have conversion rights into shares of common stock of Empire.
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Management has considered these plans in evaluating FASB ASC 205-40, Presentation of Financial Statements - Going Concern. Management believes the above actions are sufficient to allow Empire to meet its obligations as they become due within one year after the date the financial statements are issued. Management believes that its plans, and support from the existing related-party stockholders discussed above, is probable and has alleviated the substantial doubt regarding Empire’s ability to continue as a going concern.
Recent Developments
Empire has completed 13 wells in North Dakota related to our Starbuck Drilling Program during the year ended December 31, 2024.
On February 16, 2024, Empire issued a Promissory Note to Energy Evolution, a related party. Energy Evolution advanced Empire $5.0 million. On May 24, 2024, Energy Evolution elected to convert the Note to shares of common stock of Empire and received 800,000 shares under the terms of the Promissory Note. See Note 7 for further details.
In April 2024, the Company completed a subscription rights offering (the "April Rights Offering”) which raised gross proceeds of approximately $20.7 million. Each subscription right entitled the holder to purchase 0.161 shares of common stock at a subscription price of $5.00 per share per one whole share of common stock. The subscription rights were non-transferable and not listed for trading on any stock exchange or market.
On April 9, 2024, Empire partially exercised a purchase option originally issued on August 9, 2023, (the "Purchase Option”) to acquire additional working interests in certain of Empire’s New Mexico properties from Energy Evolution. The additional assets acquired represent approximately 60% of the total assets collectively acquired by Empire and Energy Evolution in the third quarter of 2023 (the "Option Assets”). As consideration, upon closing of the partial exercise of the Purchase Option, Empire issued Energy Evolution 600,000 shares of common stock of Empire based on an agreed upon price of $5.00 per share for an aggregate agreed upon value of $3.0 million which was 60% of the purchase price of $5.0 million under the Purchase Option.
On August 8, 2024, Empire successfully extended the Purchase Option with the issuance of 16,800 shares of common stock to Energy Evolution to obtain the right to acquire the remaining Option Assets for an exercise price of $2.0 million subject to certain adjustments and payable in cash, unless the parties agree that some or all may be paid by issuance of common stock to Energy Evolution. The Purchase Option expires on August 9, 2026.
In November 2024, Empire completed a subscription rights offering (the "November Rights Offering”) which raised gross proceeds of $10.0 million. Each subscription right entitled the holder to purchase 0.063 shares of common stock at a subscription price of $5.05 per share per one whole share of common stock. The subscription rights were non-transferable and not listed for trading on any stock exchange or market.
On November 18, 2024, the Company entered into the First Amendment to the Credit Facility (the “First Amendment”) to increase the initial maximum revolver commitment to $20.0 million through December 29, 2026. See Note 7 for further details.
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Production and Operating Data
The following table sets forth a summary of our production and operating data:
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
Production and operating data:
| ||||||||
Net sales volumes: | ||||||||
| Oil (Bbl) | 581,159 | 487,869 | ||||||
| Natural gas (Mcf) | 916,955 | 854,274 | ||||||
| Natural gas liquids (Bbl) | 150,091 | 136,013 | ||||||
| Total (Boe) | 884,076 | 766,261 | ||||||
| Average price per unit: | ||||||||
| Oil (1) | $ | 71.44 | $ | 75.19 | ||||
| Natural gas | $ | 0.37 | $ | 2.02 | ||||
| Natural gas liquids | $ | 14.21 | $ | 12.21 | ||||
| Total (Boe) | $ | 49.76 | $ | 52.29 | ||||
| Operating costs and expenses per Boe: | ||||||||
| Lease operating expense (excluding workovers) | $ | 24.46 | $ | 21.70 | ||||
| Workovers | $ | 6.71 | $ | 15.65 | ||||
| Total Lease operating expense | $ | 31.16 | $ | 37.36 | ||||
| Production and ad valorem taxes | $ | 4.26 | $ | 3.97 | ||||
| Depreciation, depletion, amortization and accretion | $ | 12.74 | $ | 6.33 | ||||
| General & administrative (excluding stock-based compensation) | $ | 14.23 | $ | 15.71 | ||||
| Stock-based compensation | $ | 2.44 | $ | 4.10 | ||||
| Total General & administrative | $ | 16.67 | $ | 19.81 | ||||
(1) Excludes the effect of net cash receipts from (payments on) derivatives.
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Results of Operations
The following table reflects our summary of operating information. Because of normal production declines, increased or decreased drilling activity and the effects of acquisitions, the historical information presented below should not be interpreted as indicative of future results.
| For the Years Ended December 31, | Percent | |||||||||||
| 2024 | 2023 | Change | ||||||||||
| Oil revenues | $ | 41,515,661 | $ | 36,684,494 | 13% | |||||||
| Natural gas revenues | 343,503 | 1,726,754 | -80% | |||||||||
| NGL revenues | 2,132,666 | 1,660,256 | 28% | |||||||||
| Total product revenues | 43,991,830 | 40,071,504 | ||||||||||
| Lease operating expense | 27,545,028 | 28,625,481 | -4% | |||||||||
| Production and ad valorem taxes | 3,770,078 | 3,044,411 | 24% | |||||||||
| Depreciation, depletion, amortization and accretion | 11,263,010 | 4,852,555 | 132% | |||||||||
| General and administrative expense (excluding stock-based compensation) | 12,581,859 | 12,034,185 | 5% | |||||||||
| Stock-based compensation | 2,155,774 | 3,144,750 | -31% | |||||||||
| Cash-based interest expense | 894,282 | 650,637 | 37% | |||||||||
| Non-cash interest expense | 620,987 | 349,790 | 78% | |||||||||
| Operating Loss | (13,665,457 | ) | (11,625,091 | ) | 18% | |||||||
| Net Loss | (16,197,989 | ) | (12,469,605 | ) | 30% | |||||||
Revenues
Revenues for 2024 increased compared to prior year primarily due to higher oil volumes in North Dakota due to our Starbuck Drilling Program partially offset by a slight overall decline in commodity prices.
Realized oil prices for 2024 were approximately $71.44 per barrel, while realized prices for the prior year were approximately $75.19 per barrel, a decrease in price of approximately 5%. Oil volumes were higher by approximately 93,000 barrels or 19% primarily due to new wells completed in North Dakota during the third quarter of 2024 as well as the acquisition of additional working interest in New Mexico.
Realized natural gas prices for 2024 were approximately $0.37 per Mcf, while realized prices for the prior year were approximately $2.02 per Mcf, a decrease in price of approximately 82%. This is primarily due to the depressed natural gas prices in the third quarter of 2024 in New Mexico.
Realized NGLs prices for 2024 were approximately $14.21 per barrel, while realized prices for the prior year were approximately $12.21 per barrel, an increase in price of approximately 16%.
Lease Operating Expense and Production Taxes
Lease operating expense was lower in 2024 primarily due to lower workover activities partially offset by higher expenses related to an increase in production. Lease operating expense includes approximately $5.9 million of total workover expense for 2024 as compared to approximately $12.0 million for 2023. The higher workover expense in 2023 was primarily in New Mexico as Empire continued to work over wells in the region to enhance and maintain production.
Production taxes were higher for 2024 compared to 2023 as a result of the higher product revenues discussed above.
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Depreciation, Depletion, Amortization, Accretion and Impairment
The higher DD&A in 2024 as compared to 2023 is due in part to the increase in production, the acquisition of additional working interest in New Mexico as well as the impact of the capitalized costs associated with the new drilling activity as part of our Starbuck Drilling Program in North Dakota. Accretion also increased slightly from prior period due to the new drilling activity.
We assess our oil and gas properties for impairment when circumstances indicate the carrying value may be greater than its estimated future net cash flows. There was no impairment recorded during the years ended December 31, 2024 and 2023.
General and Administrative Expense (excluding stock-based compensation)
General and Administrative Expense (excluding stock-based compensation) increased primarily due to an increase in salaries and benefits associated with an increase in employee headcount.
Stock-based Compensation
We utilize stock-based compensation to compensate members of management and retain talented personnel. Our stock-based compensation decreased in 2024 due to a lower number of awards in 2024. We anticipate stock-based compensation to continue to be utilized in 2025 and beyond to attract and retain talented personnel and compensate our board members and consultants.
Interest Expense
Cash-based interest expense increased slightly due to a higher outstanding balance under our Credit Facility partially offset by lower interest rates. We have minimal interest-bearing vehicle and equipment notes payable.
Non-cash interest expense is primarily attributable to the conversion to equity of the related party note payable as described in Note 7 of Notes to Consolidated Financial Statements.
Income taxes
We have generated net operating losses since inception, which would normally reflect a tax benefit in the consolidated statement of operations and a deferred asset on the consolidated balance sheet. However, because of the current uncertainty as to our ability to achieve sustained profitability and the potential limitation of NOL carryforwards, a full valuation allowance has been established that offsets the amount of any tax benefit available for each period presented in the consolidated statements of operations.
We had a loss before income taxes for 2024 and 2023, respectively, which the tax benefit was offset by a change in the valuation allowance. For 2024 and 2023, our effective tax rates were 0% and 1%, respectively.
Liquidity
As noted below, our working capital is negative as of December 31, 2024, which is primarily the result of a lower cash balance due to capital spending as part of our Starbuck Drilling Program and return-to-production efforts in Texas. As of December 31, 2024, we had approximately $2.3 million in cash on hand and approximately $8.7 million available under our Credit Facility. Empire will require additional funds to satisfy the payables discussed above which are greater than estimated cash flows from operations over the next 12 months. Phil Mulacek and Energy Evolution, both related parties of Empire and our largest two stockholders, owning 21.2% and 31.9%, respectively, of the common shares outstanding as of December 31, 2024, have indicated that they will, and have the ability to, provide sufficient support to sustain the operating, investing, and financing activities of Empire, as necessary. In addition to the April Rights Offering and November Rights Offering, management continues to seek additional sources of capital via the debt or equity markets to improve liquidity going forward. See Liquidity and Going Concern in Note 1 of Notes to Consolidated Financial Statements for further discussion of management’s plans.
Empire expects to continue to incur costs related to drilling activities in core areas as well as future oil and natural gas acquisitions in core areas. During 2024, Empire has incurred approximately $42.2 million of additions to oil and natural gas properties, primarily related to the drilling program in the Starbuck field of North Dakota. It is expected that Empire will use a combination of debt or equity issuances, cash on hand, and cash flows from operations to fund capital programs, ongoing operations, and any potential acquisitions.
31
Working Capital
Working capital is presented in the table below. The decrease of approximately $2.6 million was primarily driven by a lower cash balance due to increased capital spending related to the Starbuck Drilling Program in North Dakota.
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Current Assets | $ | 12,350,945 | $ | 18,744,904 | ||||
| Current Liabilities | 21,270,471 | 25,049,572 | ||||||
| Working Capital | $ | (8,919,526 | ) | $ | (6,304,668 | ) | ||
Cash Flows
The following table summarizes our statements of cash flows:
| For the Years Ended December 31, | ||||||||||||
| Cash flows provided by (used in): | 2024 | 2023 | Change | |||||||||
| Operating activities | $ | 6,157,003 | $ | (9,887,500 | ) | $ | 16,044,503 | |||||
| Investing activities | (53,869,461 | ) | (14,767,339 | ) | (39,102,122 | ) | ||||||
| Financing activities | 42,171,414 | 20,502,905 | 21,668,509 | |||||||||
Cash Flows from Operating Activities
The impact of higher oil production and lower workover expenses in 2024 compared to 2023 contributed to the increase in cash flows from operating activities.
Cash Flows from Investing Activities
Cash flows from investing activities in 2024 include approximately $42.2 million of additions to oil and gas properties compared to approximately $25.0 million in 2023 primarily due to the development of our operations as part of our Starbuck Drilling Program in North Dakota.
In 2023, we received approximately $2.8 million due to the release of a negotiated sinking fund requirement and acquired additional interest in our New Mexico oil and gas properties for approximately $2.0 million.
Cash Flows from Financing Activities
Cash flow from financing activities in 2024 include proceeds from the April Rights Offering and the November Rights Offering of approximately $30.5 million, net of transaction costs (see Note 9). In addition, cash flows from financing activities in 2024 include $5.0 million from a promissory note issued by the Company to a related party and approximately $6.7 million borrowed on the Credit Facility (see Note 7).
In 2024, we received approximately $0.6 million from stock issuances and warrant exercises. In 2023, we received approximately $12.5 million from stock issuances and warrant exercises.
Capital Resources
General
Empire’s primary sources of short-term liquidity are cash and cash equivalents, net cash provided by operating activities, and issuance of debt or equity securities. Empire’s short- and long-term liquidity requirements consist primarily of capital expenditures, acquisitions of oil and natural gas properties, payments of contractual obligations, and working capital obligations. Funding for these requirements may be provided by any combination of Empire’s sources of liquidity. Although Empire expects that its sources of funding will be adequate to fund its liquidity requirements, no assurance can be given that such funding sources will be adequate to meet Empire’s future needs.
32
Capital Expenditures
For 2024, Empire incurred approximately $42.2 million of additions to oil and natural gas properties which primarily reflects continued drilling and completions activity related to our Starbuck Drilling Program in North Dakota. For 2023, additions to oil and natural gas properties totaled $27.0 million including $2.1 million related to acquisitions. The approximate $25.0 million not related to acquisitions primarily reflects development of our North Dakota operations.
Related Party Transactions
At times the Company may enter into transactions with related parties. These transactions primarily occur with our two largest shareholders, Phil Mulacek and Energy Evolution, and are approved by the board of directors. See Note 14 for further discussion on related party activity during the year.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements.
Critical Accounting Estimates
The preparation of financial statements in conformity with accounting principles generally accepted in the United States (“US GAAP”) requires management to use judgment to make estimates and assumptions that affect certain amounts reported in the consolidated financial statements. As additional information becomes available, these estimates and assumptions are subject to change and thus impact amounts reported in the future. Because estimates and assumptions require significant judgment, future actual results could differ from those estimates and could have a significant impact on our results of operations, financial position and cash flows. We re-evaluate our estimates and assumptions at least on a quarterly basis and periodically update the estimates used in the preparation of the financial statements based on management’s latest assessment of the current and projected business and general economic environment. There have been no significant changes to Empire’s critical accounting estimates during the year ended December 31, 2024. In our management’s opinion, the more significant reporting areas impacted by management’s judgments and estimates are as follows:
Successful Efforts Method of Accounting for Oil and Natural Gas Activities
We use the successful efforts method of accounting for oil and natural gas operations. Under this method, costs to acquire oil and natural gas properties, drill successful exploratory wells, drill and equip development wells, and install production facilities are capitalized. Estimated proved oil and natural gas reserves, management’s outlook on commodity prices and projected future cash flows of oil and natural gas reserves are a significant part of our financial calculations. The following are examples of how these estimates affect financial results:
| · | an increase (decrease) in estimated proved oil, natural gas and NGLs reserves can reduce (increase) our unit-of-production depletion and amortization rates; and |
| · | changes in the oil, natural gas and NGLs reserves and the projected future cash flows from our properties can impact our periodic impairment analysis. |
Proved oil and natural gas reserves are the estimated quantities of oil, natural gas and NGLs which geological and engineering data demonstrate with reasonable certainty to be recoverable in future periods from known reservoirs under existing economic and operating conditions. Reserve quantities and future cash flows included in this report are prepared in accordance with guidelines established by the SEC and the FASB. The accuracy of reserve estimates is a function of:
| · | The quality and quantity of available data; |
| · | The interpretation of that data; |
| · | The accuracy of various mandated economic assumptions; and |
| · | The judgments of the persons preparing the estimates. |
Proved reserves information included in this report is based on estimates prepared by independent petroleum engineers, CG&A. The independent petroleum engineers evaluated 100% of our estimated proved producing reserve quantities and their related future net cash flows as of December 31, 2024. Estimates prepared by others may be higher or lower than these estimates. Because these estimates depend on many assumptions, all of which may differ substantially from actual results, reserve estimates may be different from the quantities of oil and natural gas that are ultimately recovered. Management may make revisions to reserve estimates throughout the year as additional information becomes available. Such changes could trigger an impairment of our oil and natural gas properties and have an impact on our depletion expense prospectively. For example, a change of 10 percent in our total proved reserves could change our annual depletion expense by approximately $0.9 million. The actual impact would depend on the specific areas impacted.
33
Impairment of Oil and Gas Properties
We assess our proved properties for impairment using estimates of future undiscounted cash flows. This assessment requires significant judgment and assumptions including commodity price outlooks, estimates of reserve quantities, expected lease operating costs and capital costs. An impairment expense could result if oil and gas prices decline in the future as it may not be economic to develop some of these unproved properties. We performed an assessment as of December 31, 2024 and 2023, and did not identify any impairments, respectively.
Asset Retirement Obligation
Asset retirement obligations (“ARO”) consist primarily of estimated future costs associated with the plugging and abandonment of oil and natural gas wells, removal of equipment and facilities from leased acreage, and land restoration in accordance with applicable local, state and federal laws. The discounted fair value of an ARO liability is required to be recognized in the period in which it is incurred, with the associated asset retirement cost capitalized as part of the carrying cost of the oil and natural gas asset. The recognition of an ARO requires that management make numerous assumptions regarding such factors as the estimated probabilities, amounts and timing of settlements; the credit-adjusted risk-free rate to be used; inflation rates; and future advances in technology. In periods subsequent to the initial measurement of the ARO, we must recognize period-to-period changes in the liability resulting from the passage of time and revisions to either the timing or the amount of the original estimate of undiscounted cash flows.
Stock-Based Compensation
We recognize stock-based compensation expense associated with restricted stock units and options. We account for forfeitures of equity-based incentive awards as they occur. Stock-based compensation expense related to time-based restricted stock units is based on the price of our common stock on the grant date. Stock-based compensation related to options is the fair value of the option recognized over the vesting period. The fair value of an option is determined using the Black-Scholes option valuation with the following assumption inputs: dividend yield, expected annual volatility, risk free interest rate and an expected life.
Income Taxes and Uncertain Tax Positions
Our tax provision is based upon the tax laws and rates in effect in the applicable jurisdiction in which operations are conducted and income is earned. As part of the process of preparing the consolidated financial statements, management is required to estimate the income tax provision. This process involves estimating the actual current tax exposure together with assessing temporary differences resulting from differing treatment of items, such as depreciation, amortization and certain accrued liabilities for tax and accounting purposes.
Deferred tax expense or benefit represents the change in the balance of deferred tax assets or liabilities. Valuation allowances are established to reduce deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. At December 31, 2024 and 2023, a full valuation allowance for deferred tax assets was recorded.
Management applies the accounting standards related to uncertainty in income taxes. This accounting guidance clarifies the accounting for uncertainties in income taxes by prescribing a minimum recognition threshold that a tax position is required to meet before being recognized in the consolidated financial statements. It requires that we recognize in the consolidated financial statements the financial effects of a tax position, if that position is more likely than not of being sustained upon examination, including resolution of any appeals or litigation processes, based upon the technical merits of the position. It also provides guidance on measurement, classification, interest, penalties and disclosure. We had no uncertain tax positions at December 31, 2024, or December 31, 2023.
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| ITEM 7A. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK. |
We are a smaller reporting company as defined by Rule 12b-2 of the Exchange Act and are not required to provide this information.
| ITEM 8. | FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA. |
The financial statements of the Company are set forth at the end of this Form 10-K.
| ITEM 9. | CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE. |
None.
| ITEM 9A. | CONTROLS AND PROCEDURES. |
Evaluation of Disclosure Controls and Procedures
As of the end of the period covered by this report, the Company carried out an evaluation under the supervision and participation of the Company’s Principal Executive Officer/Principal Financial Officer, along with our management, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures as defined in Exchange Act Rule 13a-15(e). Based on this evaluation, the Company’s Principal Executive Officer/Principal Financial Officer concluded that the disclosure controls and procedures were effective, as of the end of the period covered by this report, in ensuring the information required to be disclosed by the Company in the reports it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to management, including the Company’s Chief Executive Officer (Principal Executive Officer/Principal Financial Officer), to allow timely decisions regarding required disclosure.
Inherent Limitations on Effectiveness of Controls
The Company’s disclosure controls and procedures and internal control over financial reporting are designed to provide reasonable assurance of achieving their desired objectives. Management recognizes that a control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of their inherent limitations, disclosure controls and procedures and internal control over financial reporting may not prevent or detect all errors or misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
35
Management's Report on Internal Control Over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Exchange Act Rule 13a-15(f). The Company’s internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.
Under the supervision and with the participation of the Company’s management, including its Principal Executive Officer/Principal Financial Officer, the Company conducted an evaluation of the effectiveness of its internal control over financial reporting based on the framework established by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) as set forth in Internal Control - Integrated Framework. Based on our evaluation under that framework, our management concluded that our internal control over financial reporting is effective as of December 31, 2024.
Changes in Internal Control over Financial Reporting
While we continue to implement design enhancements to our internal control procedures, we believe that, there were no changes to our internal control over financial reporting which were identified in connection with the evaluation required by Rules 13a-15(d) or 15d-15(d) under the Exchange Act during the fourth quarter of 2024 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
Attestation Report of Registered Public Accounting Firm
This report does not contain an attestation report of our independent registered public accounting firm related to internal control over financial reporting because the rules for smaller reporting companies provide an exemption from the attestation requirement.
| ITEM 9B. |
The Company was not informed by any of its directors or Section 16 officers of the adoption or termination of a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as those terms are defined in Item 408 of Regulation S-K, during the fourth quarter of 2024.
| ITEM 9C. | DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS. |
Not applicable.
36
PART III
| ITEM 10. | DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE. |
The information called for by this Item 10 is incorporated herein by reference to our definitive Proxy Statement for 2025 annual meeting of stockholders (“2025 Proxy Statement”) to be filed with the SEC no later than 120 days following the fiscal year ended December 31, 2024.
| ITEM 11. | EXECUTIVE COMPENSATION. |
The information called for by this Item 11 is incorporated herein by reference to our 2025 Proxy Statement to be filed with the SEC no later than 120 days following the fiscal year ended December 31, 2024.
| ITEM 12. | SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS. |
The information called for by this Item 12 is incorporated herein by reference to our 2025 Proxy Statement to be filed with the SEC no later than 120 days following the fiscal year ended December 31, 2024.
| ITEM 13. | CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE. |
The information called for by this Item 13 is incorporated herein by reference to our 2025 Proxy Statement to be filed with the SEC no later than 120 days following the fiscal year ended December 31, 2024.
| ITEM 14. | PRINCIPAL ACCOUNTANT FEES AND SERVICES. |
The information called for by this Item 14 is incorporated herein by reference to our 2025 Proxy Statement to be filed with the SEC no later than 120 days following the fiscal year ended December 31, 2024.
37
PART IV
| ITEM 15. | EXHIBITS AND FINANCIAL STATEMENT SCHEDULES. |
| (a) | (1) Financial Statements |
The financial statements under this item are included in Item 8 of Part II of this Annual Report on Form 10-K.
| (2) Schedules |
NONE
| (3) Exhibits |
| Exhibit No. | Description | |
| 2.1 |
| |
| 3.1 |
| |
| 3.2 |
| |
| 3.3 |
| |
| 4.1 |
| |
| 4.2 |
| |
| 10.1* |
| |
| 10.2* |
| |
| 10.3 |
| |
| 10.4* |
| |
| 10.5 |
| |
| 10.6 |
| |
| 10.7* |
|
38
| 10.8* |
| |
| 10.9* |
| |
| 10.10* |
| |
| 10.11* |
|
| 10.12* |
| |
| 10.13 |
| |
| 10.14 |
| |
| 10.15 |
| |
| 10.16 |
| |
| 10.17 |
| |
| 10.18 |
| |
| 10.19 |
| |
| 10.20 |
| |
| 10.21 |
| |
| 10.22 |
|
39
| 10.23 |
| |
| 10.24 |
| |
| 10.25 |
| |
| 10.26 |
| |
| 10.27 |
| |
| 10.28* |
| |
| 10.29 |
| |
| 10.30 |
| |
| 19 | Empire Petroleum Corporation Insider Trading Policy (submitted herewith).
| |
| 21 | Subsidiaries of Empire Petroleum Corporation (submitted herewith). |
| 23.1 | Consent of Grant Thornton LLP (submitted herewith).
| |
| 23.2 | Consent of Cawley, Gillespie & Associates, Inc. (submitted herewith).
| |
| 31.1 |
| |
| 31.2 |
| |
| 32.1 | Section 1350 Certification of Michael R. Morrisett, Chief Executive Officer (submitted herewith).
| |
| 32.2 |
| |
| 97* |
| |
| 99.1 | Cawley, Gillespie & Associates, Inc. Summary Report (submitted herewith).
| |
| 101 | Financial Statements for Inline XBRL format (submitted herewith).
| |
| 104 | Cover Page Interactive Data File (embedded within Inline XBRL document). |
*Indicates a management contract or compensatory plan or arrangement identified under the requirements of Item 15 of Form 10-K.
| ITEM 16. | FORM 10-K SUMMARY. |
None.
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SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Empire Petroleum Corporation
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| Date: March 27, 2025 | By: | /s/ Michael R. Morrisett | |
| Name: Michael R. Morrisett | |||
| Title: President and Chief Executive Officer | |||
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
| Signature | Title | Date | ||
| /s/ Michael R. Morrisett | Director, President and Chief Executive Officer | March 27, 2025 | ||
| MICHAEL R. MORRISETT | (Principal Executive Officer and Principal Financial Officer) | |||
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| /s/ Matthew E. Watson | Chief Accounting Officer | March 27, 2025 | ||
| MATTHEW E. WATSON | (Principal Accounting Officer) | |||
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| /s/ Phil E. Mulacek | Director and Chairman of the Board | March 27, 2025 | ||
| PHIL E. MULACEK | ||||
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| /s/ Andrew L. Lewis | Director | March 27, 2025 | ||
| ANDREW L. LEWIS | ||||
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| /s/ Mason H. Matschke | Director | March 27, 2025 | ||
| MASON H. MATSCHKE | ||||
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| /s/ Benjamin J. Marchive II | Director | March 27, 2025 | ||
| BENJAMIN J. MARCHIVE II | ||||
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| /s/ J. Kevin Vann | Director | March 27, 2025 | ||
| J. KEVIN VANN |
41
EMPIRE PETROLEUM CORPORATION
CONSOLIDATED FINANCIAL STATEMENTS
TABLE OF CONTENTS
42
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Board of Directors and Stockholders
Empire Petroleum Corporation
Opinion on the financial statements
We have audited the accompanying consolidated balance sheets of Empire Petroleum Corporation (a Delaware corporation) and subsidiaries (the “Company”) as of December 31, 2024 and 2023, the related consolidated statements of operations, changes in stockholders’ equity, and cash flows for each of the two years in the period ended December 31, 2024, and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the two years in the period ended December 31, 2024, in conformity with accounting principles generally accepted in the United States of America.
Basis for opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical audit matters
Critical audit matters are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. We determined that there are no critical audit matters.
/s/
We have served as the Company’s auditor since 2022.
March 27, 2025
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED BALANCE SHEETS
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| ASSETS | ||||||||
| Current Assets: | ||||||||
| Cash | $ | $ | ||||||
| Accounts Receivable | ||||||||
| Derivative Instruments | ||||||||
| Inventory | ||||||||
| Prepaids | ||||||||
| Total Current Assets | ||||||||
| Property and Equipment: | ||||||||
| Oil and Natural Gas Properties, Successful Efforts | ||||||||
| Less: Accumulated Depreciation, Depletion and Impairment | ( | ) | ( | ) | ||||
| Total Oil and Gas Properties, Net | ||||||||
| Other Property and Equipment, Net | ||||||||
| Total Property and Equipment, Net | ||||||||
| Other Noncurrent Assets | ||||||||
| Total Assets | $ | $ | ||||||
| ||||||||
| LIABILITIES AND STOCKHOLDERS' EQUITY | ||||||||
| Current Liabilities: | ||||||||
| Accounts Payable | $ | $ | ||||||
| Accrued Expenses | ||||||||
| Current Portion of Lease Liability | ||||||||
| Current Portion of Note Payable - Related Party (Note 7) | ||||||||
| Current Portion of Long-Term Debt | ||||||||
| Total Current Liabilities | ||||||||
| Long-Term Debt | ||||||||
| Long Term Lease Liability | ||||||||
| Asset Retirement Obligations | ||||||||
| Total Liabilities | ||||||||
| Commitments and Contingencies (Note 15) | ||||||||
| Stockholders' Equity: | ||||||||
| Series A Preferred Stock - $ Par Value, Shares Authorized, | ||||||||
| and Shares Issued and Outstanding, Respectively | ||||||||
| Common Stock - $ Par Value Shares Authorized, | ||||||||
| and Shares Issued and Outstanding, Respectively | ||||||||
| Additional Paid-in-Capital | ||||||||
| Accumulated Deficit | ( | ) | ( | ) | ||||
| Total Stockholders' Equity | ||||||||
| Total Liabilities and Stockholders' Equity | $ | $ | ||||||
The accompanying notes are an integral part of these consolidated financial statements.
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Revenue: | ||||||||
| Oil Sales | $ | $ | ||||||
| Gas Sales | ||||||||
| NGL Sales | ||||||||
| Total Product Revenues | ||||||||
| Other | ||||||||
| Loss on Derivatives | ( | ) | ( | ) | ||||
| Total Revenue | ||||||||
| Costs and Expenses: | ||||||||
| Lease Operating Expense | ||||||||
| Production and Ad Valorem Taxes | ||||||||
| Depletion, Depreciation & Amortization | ||||||||
| Accretion of Asset Retirement Obligation | ||||||||
| General and Administrative: | ||||||||
| General and Administrative | ||||||||
| Stock-Based Compensation | ||||||||
| Total General and Administrative | ||||||||
| Total Cost and Expenses | ||||||||
| Operating Loss | ( | ) | ( | ) | ||||
| Other Income and (Expense): | ||||||||
| Interest Expense | ( | ) | ( | ) | ||||
| Other Income (Expense) | ( | ) | ||||||
| Loss Before Taxes | ( | ) | ( | ) | ||||
| Income Tax Benefit | ||||||||
| Net Loss | $ | ( | ) | $ | ( | ) | ||
| Net Loss per Common Share: | ||||||||
| Basic | $ | ( | ) | $ | ( | ) | ||
| Diluted | $ | ( | ) | $ | ( | ) | ||
| Weighted Average Number of Common Shares Outstanding: | ||||||||
| Basic | ||||||||
| Diluted | ||||||||
The accompanying notes are an integral part of these consolidated financial statements.
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY
| Common Stock | Preferred Stock | |||||||||||||||||||||||||||
| Shares | Par Value | Shares | Par Value | Additional Paid-in-Capital | Accumulated Deficit | Total | ||||||||||||||||||||||
| Balances as of December 31, 2022 | $ | $ | $ | $ | ( | ) | $ | |||||||||||||||||||||
| Net Loss | — | — | ( | ) | ( | ) | ||||||||||||||||||||||
| Impact of Former CEO Settlement | — | — | ( | ) | ( | ) | ||||||||||||||||||||||
| Stock Issued for Purchase Option (Note 3) | — | |||||||||||||||||||||||||||
| Warrants Exercised | — | |||||||||||||||||||||||||||
| Issuance of Shares for Redemption of Notes | — | |||||||||||||||||||||||||||
| Issuance of Shares in Private Transaction | — | |||||||||||||||||||||||||||
| Stock-Based Compensation | — | |||||||||||||||||||||||||||
| Balances as of December 31, 2023 | $ | $ | $ | $ | ( | ) | $ | |||||||||||||||||||||
| Net Loss | — | — | ( | ) | ( | ) | ||||||||||||||||||||||
| Rights Offerings (Note 9) | — | |||||||||||||||||||||||||||
| Partial Conversion of Option to Purchase (Note 3) | — | |||||||||||||||||||||||||||
| Warrants Exercised | — | |||||||||||||||||||||||||||
| Conversion of Related-Party Note (Note 7) | — | |||||||||||||||||||||||||||
| Stock-Based Compensation | — | |||||||||||||||||||||||||||
| Balances as of December 31, 2024 | $ | $ | $ | $ | ( | ) | $ | |||||||||||||||||||||
The accompanying notes are an integral part of these consolidated financial statements.
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Cash Flows From Operating Activities: | ||||||||
| Net Loss | $ | ( | ) | $ | ( | ) | ||
| Adjustments to Reconcile Net Loss to Net Cash | ||||||||
| Provided By (Used In) Operating Activities: | ||||||||
| Stock-Based Compensation | ||||||||
| Amortization of Right of Use Assets | ||||||||
| Depreciation, Depletion and Amortization | ||||||||
| Accretion of Asset Retirement Obligation | ||||||||
| Loss on Commodity Derivatives | ||||||||
| Settlement on or Purchases of Derivative Instruments | ( | ) | ||||||
| Loss on Financial Derivatives (See Note 7) | ||||||||
| Amortization of Debt Discount on Convertible Notes | ||||||||
| Loss on Extinguishment of Debt | ||||||||
| Change in Operating Assets and Liabilities: | ||||||||
| Accounts Receivable | ( | ) | ( | ) | ||||
| Inventory, Oil in Tanks | ( | ) | ||||||
| Prepaids, Current | ||||||||
| Accounts Payable | ||||||||
| Accrued Expenses | ( | ) | ||||||
| Other Long Term Assets and Liabilities | ( | ) | ( | ) | ||||
| Net Cash Provided By (Used In) Operating Activities | ( | ) | ||||||
| Cash Flows From Investing Activities: | ||||||||
| Acquisition of Oil and Natural Gas Properties | ( | ) | ||||||
| Capital Expenditures - Oil and Natural Gas Properties (1) | ( | ) | ( | ) | ||||
| Purchase of Other Fixed Assets | ( | ) | ( | ) | ||||
| Cash Paid for Right of Use Assets | ( | ) | ( | ) | ||||
| Sinking Fund Deposit | ||||||||
| Net Cash Used In Investing Activities | ( | ) | ( | ) | ||||
| Cash Flows From Financing Activities: | ||||||||
| Borrowings on Credit Facility | ||||||||
| Proceeds from Promissory Note - Related Party (Note 7) | ||||||||
| Proceeds from Rights Offerings, net of transaction costs (Note 9) | ||||||||
| Principal Payments of Debt | ( | ) | ( | ) | ||||
| Proceeds from Stock Issuance and Warrant Exercises | ||||||||
| Net Cash Provided By Financing Activities | ||||||||
| Net Change in Cash | ( | ) | ( | ) | ||||
| Cash - Beginning of Period | ||||||||
| Cash - End of Period | $ | $ | ||||||
| Supplemental Cash Flow Information: | ||||||||
| Cash Paid for Interest | $ | $ | ||||||
| (1) |
The accompanying notes are an integral part of these consolidated financial statements.
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EMPIRE PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 - Organization and Basis of Presentation
Empire Petroleum Corporation (the “Company”, collectively with its subsidiaries) is an independent energy company operator engaged in optimizing developed production by employing field management methods to maximize reserve recovery while minimizing costs. Empire operates the following wholly-owned subsidiaries in its areas of operations:
| ● | Empire New Mexico LLC (“Empire New Mexico”), consisting of the following entities: |
| ○ | Empire New Mexico LLC d/b/a Green Tree New Mexico | |
| ○ | Empire EMSU LLC | |
| ○ | Empire EMSU-B LLC | |
| ○ | Empire AGU LLC | |
| ○ | Empire NM Assets LLC |
| ● | Empire North Dakota (“Empire North Dakota”), consisting of the following entities: |
| ○ | Empire North Dakota LLC (“Empire North Dakota”) |
| ○ | Empire ND Acquisition LLC (“Empire NDA”) |
| ● | Empire Texas (“Empire Texas”), consisting of the following entities: |
| ○ | Empire Texas LLC |
| ○ | Empire Texas Operating LLC |
| ○ | Empire Texas GP LLC |
| ○ | Pardus Oil & Gas Operating, LP (owned 1% by Empire Texas GP LLC and 99% by Empire Texas LLC) |
| ● | Empire Louisiana LLC (“Empire Louisiana”) |
Empire was incorporated in the State of Delaware in 1985. The consolidated financial statements of Empire Petroleum Corporation and subsidiaries include the accounts of the Company and its wholly-owned subsidiaries. The terms "Company,” "we,” "us,” "our,” and similar terms refer to Empire Petroleum Corporation and its subsidiaries.
Liquidity and Going Concern
The Company has a revolving line of credit agreement with Equity Bank which requires the Company to maintain compliance with certain financial covenants computed on a quarterly and annual basis. As of December 31, 2024, the Company was in compliance with all required covenants and projected to be in compliance with all debt covenants over the next 12 months. However, the Company was in default of its covenants in the third quarter of 2024 but obtained a waiver on November 12, 2024, to alleviate all prior defaults. The Company carried a negative working capital of approximately $8.9 million as of December 31, 2024, an overall decline of approximately $2.6 million from the previous year. Cash on hand also declined approximately $5.5 million during the same period. The overall decline in working capital and cash is primarily driven by the Starbuck Drilling Program in North Dakota which incurred substantial capital spend. Additionally, the Company initiated a return-to-production program in Texas which incurred additional unforeseen operational costs. The additional production from these projects did not fully offset the costs incurred and contributed to the overall negative financial trend. To meet its obligations, the Company increased its revolver commitment to $20.0 million in November 2024 and had two rights offerings in April and November of 2024 which raised approximately $30.5 million of capital, net of transaction costs, to help fund the capital spend projects. Additionally, as a result of increasing its revolver commitment, the Company had approximately $8.7 million remaining unused commitment as of December 31, 2024, which can be used for future obligations. However, the revolver commitment is reduced monthly by $0.25 million commencing on December 31, 2024 (See Note 7), limiting future access to capital. While these debt and equity transactions provided additional funding towards these projects and other obligations, the Company still carried approximately $8.9 million of negative working capital at period end and future expected operating cash flows do not sufficiently meet the Company’s obligations for the next 12 months. Given the negative working capital and insufficient expected operating cash flow there is substantial doubt about the Company’s ability to continue as a going concern.
Empire has committed financial support from Phil Mulacek who owns approximately 21.2% of our common stock outstanding as of December 31, 2024, and Energy Evolution, our largest stockholder who owns approximately 31.9% of our common stock outstanding as of December 31, 2024. Both are related parties of the Company (see Note 14). Mr. Mulacek and Energy Evolution are willing and able to provide these additional funds, if required, for Empire to continue to meet its obligations over the next 12 months. These additional funds may be raised through related party warrants or a related party note payable that may or may not have conversion rights into shares of common stock of Empire.
Management has considered these plans in evaluating FASB ASC 205-40, Presentation of Financial Statements - Going Concern. Management believes the above actions are sufficient to allow Empire to meet its obligations as they become due within one year after the date the financial statements are issued. Management believes that its plans, and support from the existing related-party stockholders discussed above, is probable and has alleviated the substantial doubt regarding Empire’s ability to continue as a going concern.
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Note 2 – Summary of Significant Accounting Policies
Principles of Consolidation
The consolidated financial statements include the accounts and balances of the Company and have been prepared in accordance with US GAAP. All intercompany accounts and transactions have been eliminated in consolidation.
Use of Estimates
The preparation of financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual results could differ from those estimates.
Estimated quantities of crude oil, natural gas and NGLs reserves are the most significant of the Company’s estimates. All reserve data used in the preparation of the consolidated financial statements, including depletion estimates, and information included in Note 19 - Supplemental Information of Oil and Natural Gas Producing Activities (Unaudited), are based on estimates. Reservoir engineering is a subjective process of estimating underground accumulations of crude oil, natural gas and NGLs. There are numerous uncertainties inherent in estimating quantities of proved crude oil, natural gas and NGLs reserves. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. As a result, reserve estimates may be different from the quantities of crude oil, natural gas and NGLs that are ultimately recovered.
Other items subject to estimates and assumptions include, but are not limited to, the carrying amounts of property, plant and equipment, asset retirement obligations, valuation allowances for deferred income tax assets, and valuation of derivative instruments. Management evaluates estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic and commodity price environment. The volatility of commodity prices results in increased uncertainty inherent in such estimates and assumptions.
Although management believes these estimates are reasonable, actual results may differ from estimates and assumptions of future events and these revisions could be material. Future production may vary materially from estimated oil and natural gas proved reserves. Actual future prices may vary significantly from price assumptions used for determining proved reserves and for financial reporting.
Out of Period Adjustments
In the third quarter of 2022, the Company identified and recorded an out-of-period adjustment related to the joint development agreement (“JDA”) discussed in Note 7. In 2023, the impact of recording this adjustment reduced other noncurrent assets and increased lease operating expense by approximately $1.3 million of which $0.8 million related to prior to 2023. The impact of the adjustment was immaterial to the prior period financial statements and thus corrected in 2023. No adjustments were made in 2024.
Accounts Receivable
Accounts receivable include estimated amounts due from crude oil, natural gas, and NGLs purchasers and from non-operating working interest owners. Accrued revenue related to product sales from purchasers and operators are due under normal trade terms, generally requiring payment within 60 days of production. For receivables from joint interest owners, the Company generally has the ability to withhold future revenue disbursements to recover any non-payment of joint interest billings.
Receivables are stated at amounts due, net of an allowance for credit losses, if necessary and are considered past due if full payment is not received by the contractual due date. The Company estimates uncollectible amounts based on the length of time that the accounts receivable has been outstanding, historical collection experience and current and future economic and market conditions, if failure to collect is expected to occur. Past due accounts are generally written off against the allowance for credit losses account only after all collection attempts have been exhausted. The Company did not have an allowance for credit losses at either December 31, 2024 or 2023.
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The Company’s accounts receivable are as follows:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Oil, Gas and NGLs receivables | $ | $ | ||||||
| Joint interest billings | ||||||||
| Joint interest billings - related party | ||||||||
| Other | ||||||||
| Total Accounts receivable | $ | $ | ||||||
Concentrations of Credit Risk
Empire’s accounts receivable are primarily receivables from oil and natural gas purchasers and joint interest owners. The oil and
natural gas purchasers consist primarily of independent marketers, major oil and natural gas companies and gas pipeline companies. Historically,
the Company has not experienced any significant losses from uncollectible accounts from its oil and natural gas purchasers. The Company
operates a substantial portion of its oil and natural gas properties. As the operator of a property we make full payments for costs associated
with the property and seek reimbursement from the other working interest owners in the property for their share of those costs. Joint
operating agreements govern the operations of an oil or natural gas well and, in most instances, provide for the offsetting of amounts
payable or receivable between the Company and its joint interest owners. Our joint interest partners consist primarily of independent
oil and natural gas producers. If the oil and natural gas exploration and production industry in general were adversely affected, the
ability of the joint interest partners to reimburse Empire could be adversely affected.
Convertible Debt and Derivative Instruments
During the year ended December 31, 2024, Empire added the following significant accounting policy and estimate relating to convertible debt and derivative liability.
In connection with Empire’s issuance of a promissory note in the first quarter of 2024, Empire bifurcated the embedded conversion option and recorded the embedded conversion option as a long-term derivative liability in Empire’s consolidated balance sheets in accordance with FASB ASC 815, Derivatives and Hedging. The convertible debt and the derivative liability associated with the promissory note were presented on the consolidated balance sheets as the long-term note payable – related party and long-term derivative instruments. The convertible debt was carried at amortized cost. The derivative liability was remeasured at each reporting period using a binomial lattice model with changes in fair value recorded in the consolidated statements of operations in other income (expense). The conversion option related to the promissory note was exercised in the second quarter of 2024. See Note 7 for further details.
The Company enters into hedge agreements to manage its exposure to oil and natural gas price fluctuations. The fair value of derivative contracts is recognized as an asset or liability on the Company’s consolidated balance sheets. Realized gain or loss is recognized as a component of revenue when the derivative contracts mature. For contracts which have not matured, an unrealized gain or loss is recorded based on the change in the fair value of the outstanding contracts.
Inventory
Inventory primarily consists of oil in tanks which has not been delivered and is valued at the lower of cost or net realizable value.
Leases
The Company’s right-of-use operating lease assets and lease liabilities are primarily for leased vehicles for field operations and office spaces. Some of these lease agreements include variable payments for non-lease components such as common area maintenance.
Oil and Natural Gas and Other Properties
The Company uses the successful efforts method of accounting for its oil and gas activities. Costs incurred are deferred until exploration and completion results are evaluated. At such time, costs of activities with economically recoverable reserves are capitalized as proven properties, and costs of unsuccessful or uneconomical activities are expensed.
Capitalized drilling costs are reviewed periodically for impairment. Costs related to impaired prospects or unsuccessful exploratory drilling are charged to expense. Management's assessment of the results of exploration activities, commodity price outlooks, planned future sales or expiration of all or a portion of such leaseholds impact the amount and timing of impairment provisions. An impairment expense could result if oil and gas prices decline in the future as it may not be economical to develop some of these unproved properties.
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Lease options are capitalized as unproved property acquisition costs and are reviewed for impairment if indicators exist that the carrying value of the lease option may not be recoverable. If the lease options become impaired, expire or are abandoned, the options will be expensed. If proved reserves are discovered after the options are exercised, these costs will be reclassified as proved property.
Depletion and amortization of producing properties is computed on the units-of-production method on a property-by-property basis. The units-of-production method is based primarily on estimates of proved reserve quantities. Due to uncertainties inherent in this estimation process, it is at least reasonably possible that reserve quantities will be revised in the near term. Changes in estimated reserve quantities are applied to depletion and amortization computations prospectively.
Other property and equipment is depreciated on the straight-line method.
Segment Reporting
The Company operates as one operating segment and one reportable segment which is engaged in the exploration, development, and production of oil, gas, and NGLs in New Mexico, North Dakota, Montana, Texas, and Louisiana, from which all of its revenues are derived and expenses incurred. All financial results are reviewed by the Chief Executive Officer (“CEO”), the Company’s Chief Operating Decision Maker (“CODM”), on a consolidated basis to evaluate performance of the Company. The single segment constitutes all of the consolidated entity and the accompanying consolidated financial statements and the notes to the accompanying consolidated financial statements are representative of such amounts. Refer to Note 18 for further discussion.
Debt Issuance Costs
Debt issuance fees, which are recorded at cost, net of amortization, are amortized over the life of the respective debt agreements utilizing the straight-line method. We had approximately $0.2 million and $0.1 million of unamortized debt issuance costs as of year-end December 31, 2024 and 2023, respectively. Unamortized debt issuance costs related to the Company’s credit facility are recorded in other noncurrent assets on the Company’s consolidated balance sheets.
Asset Retirement Obligations
The Company records the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related oil and natural gas property asset. Subsequently, the asset retirement cost included in the carrying amount of the related asset is allocated to expense through depletion of the asset. Changes in the liability due to passage of time are recognized as an increase in the carrying amount of the liability through accretion expense. Based on certain factors, including commodity prices and costs, the Company may revise its previous estimates of the liability, which would also increase or decrease the related oil and natural gas property asset.
Revenue Recognition
The Company’s revenues are comprised solely of revenues from customers and include the sale of oil, natural gas and NGLs. The Company believes that the disaggregation of revenue into these three major product types, as presented in the consolidated statements of operations, appropriately depicts how the nature, amount, timing and uncertainty of revenue and cash flows are affected by economic factors based on its single geographic region, the continental United States. Revenues are recognized at a point in time when production is sold to a purchaser at a determinable price, delivery has occurred, control has transferred and it is probable substantially all of the consideration will be collected. The Company fulfills its performance obligations under its customer contracts through delivery of oil, natural gas and NGLs and revenues are recorded on a monthly basis. The Company receives payment from one to three months after delivery. Generally, each unit of product represents a separate performance obligation. The prices received for oil, natural gas and NGLs sales under the Company’s contracts are generally derived from stated market prices which are then adjusted to reflect deductions including transportation, fractionation and processing. As a result, revenues from the sale of oil, natural gas and NGLs will decrease if market prices decline. The sales of oil, natural gas and NGLs, as presented on the consolidated statements of operations, represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling oil, natural gas and NGLs on behalf of royalty or working interest owners, the Company is acting as an agent and thus reports the revenue on a net basis. To the extent actual volumes and prices of oil and natural gas sales are unavailable for a given reporting period because of timing or information not received from third parties, the expected sales volumes and prices for those properties are estimated and recorded. Variances between the Company’s estimated revenue and actual payment are recorded in the month the payment is received. Historically, these differences have been insignificant.
At the end of each month when the performance obligation is satisfied, the variable consideration can be reasonably estimated and amounts due from customers are recorded in accounts receivable on the consolidated balance sheets. Taxes assessed by governmental authorities on oil, natural gas and NGLs sales are presented separately from such revenues in the consolidated statements of operations.
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Oil Sales
Oil production is transported from the wellhead to tank batteries or delivery points through flow-lines or gathering systems. Purchasers of the oil take delivery at the tank batteries and transport the oil by truck or at a pipeline delivery point and the Company collects a market price, net of pricing differentials. Revenue is recognized when control transfers to the purchaser at the net price received by the Company.
Natural Gas and NGLs Sales
Under the Company’s natural gas sales arrangements, the purchaser takes control of wet gas at a delivery point near the wellhead or at the inlet of the purchaser’s processing facility. The purchaser gathers and processes the wet gas and remits proceeds to the Company for the resulting natural gas and NGLs sales. Based on the nature of these arrangements, the purchaser is the Company’s processor, thus, the Company recognizes natural gas and NGLs sales based on the net amount of proceeds received from the purchaser.
Transaction Price Allocated to Remaining Performance Obligations
Substantially all of the Company’s product sales are short-term in nature with a contract term of one year or less. For these contracts, the Company has utilized the practical expedient in ASU 2024, Revenue from Contracts with Customers (“Topic 606”) which exempts the Company from the requirements to disclose the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less.
For the Company’s product sales that have a contract term greater than one year, the Company has utilized the practical expedient in Topic 606 which states the Company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these contracts, each unit of product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required.
Prior-Period Performance Obligations
The Company records revenue in the month that product is delivered to the purchaser. Settlement statements for certain natural gas and NGLs sales, however, may not be received for 30 to 90 days after the date the product is delivered, and as a result the Company is required to estimate the amount of product delivered to the purchaser and the price that will be received for the sale of the product. In these situations, the Company records the differences between its estimates and the actual amounts received for product sales in the month that payment is received from the purchaser. Any identified differences between the Company’s revenue estimates and actual revenue received have historically been insignificant. For the years ended December 31, 2024 and 2023, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material.
Stock-Based Compensation
The Company recognizes stock-based compensation expense associated with equity-based incentive awards consisting of stock options and restricted stock units. The Company accounts for forfeitures of equity-based incentive awards as they occur. Stock-based compensation expense related to equity-based awards is generally recognized as vesting occurs. See Note 10 for further discussion.
Income Taxes
The Company accounts for income taxes in accordance with the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to the taxable income in the years in which those temporary differences are expected to be recovered or settled. A valuation allowance is established if management determines it is more likely than not that some portion of a deferred tax asset will not be realized. Interest and penalties, if any, related to accrued liabilities for potential tax assessments are included in income tax benefit (expense) on the consolidated statements of operations.
The Company calculates and discloses basic earnings per share ("Basic EPS") and diluted earnings per share ("Diluted EPS"). The computation of basic earnings per share is computed by dividing earnings available to common stockholders by the weighted average number of outstanding common shares during the period.
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Diluted EPS gives effect to all dilutive potential common shares outstanding during the period. The computation of Diluted EPS does not assume conversion, exercise or contingent exercise of securities that would have an anti-dilutive effect on losses. As a result, if there is a loss from continuing operations, Diluted EPS is computed in the same manner as Basic EPS.
Fair Value Measurements
The FASB ASC 820, Fair Value Measurement (“Topic 820”) standards define fair value, establish a consistent framework for measuring fair value and establish a fair value hierarchy based on the observability of inputs used to measure fair value.
The three-level fair value hierarchy for disclosure of fair value measurements defined by Topic 820 is as follows:
Level 1 – Unadjusted, quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. An active market is defined as a market where transactions for the financial instrument occur with sufficient frequency and volume to provide pricing information on an ongoing basis.
Level 2 – Inputs, other than quoted prices within Level 1, that are either directly or indirectly observable for the asset or liability through correlation with market data at the measurement date and for the duration of the instrument’s anticipated life.
Level 3 – Prices or valuations that require unobservable inputs that are both significant to the fair value measurement and unobservable. Valuation under Level 3 generally involves a significant degree of judgment from management.
A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Where available, fair value is based on observable market prices or parameters or derived from such prices or parameters. Where observable prices or inputs are not available, valuation models are applied. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the price transparency for the instruments or market and the instrument’s complexity. The Company reflects transfers between the three levels at the beginning of the reporting period in which the availability of observable inputs no longer justifies classification in the original level. There were no transfers between fair value hierarchy levels for the years ended December 31, 2024 and 2023. See Note 17.
Related Party Transactions
Transactions between related parties are considered to be related party transactions even though they may not be given accounting recognition. FASB ASC 850, Related Party Disclosures (“Topic 850”) requires that transactions with related parties that would have influence in decision making shall be disclosed so that users of the financial statements can evaluate their significance. Related party transactions typically occur within the context of the following relationships: affiliates of the entity; entities for which investments in their equity securities is typically accounted for under the equity method by the investing entity; trusts for the benefit of employees; principal owners of the entity and members of their immediate families; management of the entity and members of their immediate families; and other parties that can significantly influence the management or operating policies of the transacting parties and can significantly influence the other to an extent that one or more of the transacting parties might be prevented from fully pursuing its own separate interests.
Recently Issued Accounting Pronouncements
The FASB periodically issues new accounting standards in a continuing effort to improve standards of financial accounting and reporting. The Company has reviewed the recently issued pronouncements and concluded that the following new accounting standards are applicable:
In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses. This ASU, as further amended, affects trade receivables, financial assets and certain other instruments that are not measured through net income. This ASU will replace the currently required incurred loss approach with an expected loss model for instruments measured at amortized cost and is effective for financial statements issued for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. The adoption of this ASU on January 1, 2023, by the Company did not have a material impact on the Company’s consolidated financial statements as the Company does not have a history of credit losses.
In August 2020, the FASB issued ASU 2020-06, Debt—Debt with Conversion and Other Options (“Subtopic 470-20”) and Derivatives and Hedging—Contracts in Entity’s Own Equity: Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity (“Subtopic 815-40”). The amendments in this ASU affect entities that issue convertible instruments and/or contracts in an entity’s own equity. The amendments in this ASU primarily affect convertible instruments issued with beneficial conversion features or cash conversion features because the accounting models for those specific features are removed. However, all entities that issue convertible instruments are affected by the amendments to the disclosure requirements of this ASU. For contracts in an entity’s own equity, the contracts primarily affected are freestanding instruments and embedded features that are accounted for as derivatives under the current guidance because of failure to meet the settlement conditions of the derivatives scope exception related to certain requirements of the settlement assessment. Also affected is the assessment of whether an embedded conversion feature in a convertible instrument qualifies for the derivatives scope exception. Additionally, the amendments in this ASU affect the diluted EPS calculation for instruments that may be settled in cash or shares and for convertible instruments. The amendments in this ASU are effective for public business entities, excluding entities eligible to be smaller reporting companies, for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years. For all other entities, the amendments are effective for fiscal years beginning after December 15, 2023, including interim periods within those fiscal years. The Board specified that an entity should adopt the guidance as of the beginning of its annual fiscal year. The Company adopted this standard on January 1, 2024 through a modified retrospective method of transition and determined it did not impact the prior period financials. The adoption also did not have a material impact on our current period consolidated financial statements.
53
In November 2023, FASB issued ASU 2023-07, Segment Reporting (“Topic 280”). This update requires that a public entity, including entities with a single reportable segment, disclose significant segment expenses that are regularly provided to the chief operating decision maker, as well as other segment items that are included in the calculation of segment profit or loss. A public entity will also be required to disclose all annual disclosures about a reportable segment's profit or loss currently required by Topic 280 in interim periods. Although a public entity is permitted to disclose multiple measures of a segment's profit or loss, at least one of the reported segment profit or loss measures should be consistent with the measurement principles used in measuring the corresponding amounts of the public entity's consolidated financial statements. Further, a public entity must disclose the title and position of the CODM as well as how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources. The amendments in this update are effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. See Note 18.
In December 2023, FASB, issued ASU 2023-09, Income Taxes: Improvements to Income Tax Disclosures (“Topic 740”). The guidance in Topic 740 improves the transparency of income tax disclosures by greater disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The standard is effective for public companies for fiscal years beginning after December 15, 2024 with early adoption permitted and should be applied prospectively. The Company is currently evaluating the impact of this standard on its consolidated financial statements and related disclosures.
In November 2024, the FASB issued ASU 2024-03, Income Statement – Reporting Comprehensive Income – Expense Disaggregation Disclosures (“Subtopic 220-40”), which expands disclosures around a public entity’s costs and expenses of specific items (i.e., employee compensation, DD&A), requires the inclusion of amounts that are required to be disclosed under US GAAP in the same disclosure as other disaggregation requirements, requires qualitative descriptions of amounts remaining in expense captions that are not separately disaggregated quantitatively, and requires disclosure of total selling expenses, and in annual periods, the definition of selling expenses. The amendment does not change or remove existing disclosure requirements. The amendment is effective for fiscal years beginning after December 15, 2026, and interim periods with fiscal years beginning after December 15, 2027. Early adoption is permitted, and the amendment can be adopted prospectively or retrospectively to any or all periods presented in the financial statements. Empire is currently assessing the impact of adopting this standard which is expected to only affect financial statement disclosures.
Note 3 – Property
Empire follows the successful efforts method of accounting for its oil and natural gas activities. Under this method, costs to acquire oil and natural gas properties and costs incurred to drill and equip development and exploratory wells are deferred until exploration and completion results are evaluated. Exploration drilling costs are expensed if recoverable reserves are not found. Upon sale or retirement of oil and natural gas properties, the costs and related accumulated depletion and amortization are eliminated from the accounts and the resulting gain or loss is recognized.
Costs incurred to maintain wells and related equipment and lease and well operating costs are charged to expense as incurred.
Depletion is calculated on a unit-of-production basis at the field level based on total proved developed reserves.
Proved oil and natural gas properties are reviewed for impairment at least annually, or as indicators of impairment arise. There have been no indicators of impairment during the years ended December 31, 2024 and 2023.
54
The aggregate capitalized costs of oil and natural gas properties are as follows:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Proved properties | $ | $ | ||||||
| Unproved properties | ||||||||
| Work in process | ||||||||
| Gross capitalized costs | ||||||||
| Accumulated depletion, amortization and impairment | ( | ) | ( | ) | ||||
| Total Oil and gas properties, net | $ | $ | ||||||
Depletion
amortization expense related to oil and gas properties for the years ended December 31, 2024 and 2023, was approximately $
Empire has completed 13 wells in North Dakota related to our Starbuck Drilling Program during the year ended December 31, 2024.
On
August 9, 2023, the Company and a subsidiary of Energy Evolution, a related party,
collectively acquired additional working interests in certain of the Company’s New Mexico properties. The Company paid $
On
April 9, 2024, Empire partially exercised the Purchase Option to acquire additional working interests in certain of Empire New Mexico’s
properties from Energy Evolution, a related party. The additional assets acquired represent approximately 60% of the total assets collectively
acquired by Empire and Energy Evolution in the third quarter of 2023 (the "Option Assets”). As consideration, upon closing
of the partial exercise of the Purchase Option, Empire issued Energy Evolution
On
August 8, 2024, Empire successfully extended the Purchase Option with the issuance of
Other property and equipment consists of operating lease assets, vehicles, office furniture, and equipment with lives ranging from three to five years. The capitalized costs of other property and equipment are as follows:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Other property and equipment, at cost | $ | $ | ||||||
| Less: accumulated depreciation | ( | ) | ( | ) | ||||
| Other property and equipment, net | $ | $ | ||||||
Depreciation
expense related to other property and equipment for the years ended December 31, 2024 and 2023, was approximately $
Note 4 - Asset Retirement Obligations
The Company’s asset retirement obligations represent the estimated present value of the estimated cash flows the Company will incur to plug, abandon and remediate its producing properties at the end of their productive lives, in accordance with applicable state laws.
55
Market risk premiums associated with asset retirement obligations are estimated to represent a component of the Company’s credit-adjusted risk-free rate that is utilized in the calculations of asset retirement obligations.
The Company’s asset retirement obligation activities are summarized in the following table:
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Asset retirement obligations, beginning of period | $ | $ | ||||||
| Liabilities incurred from drilling activity and assumed in acquisitions | ||||||||
| Revisions | ||||||||
| Liabilities settled | ( | ) | ( | ) | ||||
| Accretion expense | ||||||||
| Asset retirement obligation, end of period | $ | $ | ||||||
| Less: current portion included in Accrued expenses | ||||||||
| Asset retirement obligation, long-term | $ | $ | ||||||
The liabilities incurred from drilling activity in 2024 primarily relate to the completion of new wells as part of Empire’s North Dakota Starbuck Drilling Program. The liabilities assumed in acquisitions in 2024 relate to additional working interest acquired in New Mexico.
Note 5 – Commodity Derivative Financial Instruments
The Company has used derivative financial instruments to manage its exposure to commodity price fluctuations in the past. Commodity derivative instruments have been used to reduce the effect of volatility of price changes on the oil and natural gas the Company produces and sells. The Company does not enter into derivative financial instruments for speculative or trading purposes. The Company’s derivative financial instrument activity has consisted of swaps and put options.
The Company does not designate its derivative instruments to qualify for hedge accounting. Accordingly, the Company reflects changes in the fair value of its derivative instruments in its consolidated statements of operations as they occur. These contracts are recognized and recorded at fair value as an asset or liability on the Company’s consolidated balance sheets. Cash receipts or payments upon settlement of swaps and put options are reflected in the operating activities section of its consolidated statements of cash flows.
The following table summarizes the net realized and unrealized amounts reported in earnings related to the oil derivative instruments:
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Gain (loss) on derivatives, realized | $ | $ | ( | ) | ||||
| Gain (loss) on derivatives, unrealized | ( | ) | ||||||
| Loss on derivatives, net | $ | ( | ) | $ | ( | ) | ||
The following table represents the Company’s net cash receipts from (payments on) derivatives:
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Cash receipts from (payments on) on oil derivatives, net | $ | $ | ( | ) | ||||
The Company did not have any open commodity derivative positions as of December 31, 2024.
56
Note 6 – Accrued Expenses
The following table represents the Company’s accrued expenses:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Accrued and suspended third-party revenue | $ | $ | ||||||
| Accrued salaries and payroll taxes | ||||||||
| Accrued production taxes | ||||||||
| Asset retirement obligation - current | ||||||||
| Other | ||||||||
| Total Accrued Expenses | $ | $ | ||||||
Note 7 – Debt Including Debt with Related Parties
The following table represents the Company’s outstanding debt:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Equity Bank Credit Facility | $ | $ | ||||||
| Note Payable – Related Party | ||||||||
| Equipment and vehicle notes, | ||||||||
| Total Debt | ||||||||
| Less: Current Maturities | ( | ) | ( | ) | ||||
| Less: Note Payable – Related Party | ( | ) | ||||||
| Long-Term Debt | $ | $ | ||||||
| (1) |
On
July 7, 2021, the Company entered into the Fourth Amendment to its Senior Revolver Loan Agreement with CrossFirst Bank ("CrossFirst”)
as further amended by Letter Agreements in conjunction with redetermination dates (the “Amended Agreement”). The maximum
amount that could be advanced under the Amended Agreement was $
On
December 29, 2023, Empire North Dakota and Empire NDA ("Borrowers”),
The Credit Facility is guaranteed by the Company. Borrowers entered into a security agreement, pursuant to which the obligations under the Credit Facility are secured by liens on substantially all of the assets of Borrowers. Furthermore, the obligations under the Credit Facility are secured by a continuing, first priority mortgage lien, pledge of and security interest in not less than 80% of Borrowers’ producing oil, gas and other leasehold and mineral interests, including without limitation, those situated in the States of North Dakota and Montana.
The Credit Facility requires Borrowers to, commencing as of the fiscal quarter ended December 31, 2023, maintain (a) a current ratio of 1.0 to 1.0 or more and (b) a ratio of funded debt to EBITDAX (as defined in the Credit Facility), calculated quarterly and annually based on a trailing twelve-month basis, of no more than 3.50 to 1.00. At December 31, 2024, the Borrowers were in compliance with all required covenants under the Credit Facility.
57
On
November 18, 2024, the Company entered into the First Amendment. Pursuant to the First Amendment
On
September 19, 2023, each of Phil Mulacek, a member of the Company’s Board of Directors, and Energy Evolution made a bridge loan
to Empire North Dakota in the amount of $
Promissory Note - Related Party
On
February 16, 2024, Empire issued a promissory note in the aggregate principal amount of $
The
Note matures on February 15, 2026, (the "Maturity Date”) and accrues interest at the rate of
Empire
determined that an embedded conversion feature included in the Note required bifurcation from the host contract that is recognized as
a separate derivative liability carried at fair value.
Note Payable - Related Party
In
August 2020, Empire, through its wholly-owned subsidiary, Empire Texas, entered into a JDA with Petroleum & Independent Exploration,
LLC and related entities ("PIE”), a related party (see Note 14), dated August 1, 2020. Under the terms of the JDA, PIE performed
recompletion or workover on specified mutually agreed upon wells owned by Empire Texas. Concurrent with the JDA with PIE, Empire entered
into a term loan agreement dated August 1, 2020, whereby PIE will loan up to $
On
July 31, 2024, PIE, Empire Texas, and Empire entered into a note repayment and loan termination agreement providing for the payment
in full of the remaining outstanding amount of the approximate $
58
Note 8 - Leases
As
a lessee, the Company leases its corporate office headquarters in Tulsa, Oklahoma, and one field office.
The Company also leases vehicles primarily used in our field operations. These vehicle leases typically have a -year life.
The Company recognizes right-of-use lease expense on a straight-line basis, except for certain variable expenses that are recognized when the variability is resolved, typically during the period in which they are paid. Variable right-of-use lease payments typically include charges for property taxes, insurance, and variable payments related to non-lease components, including common area maintenance.
Right-of-use
lease expense was approximately $
Supplemental balance sheet information related to the right of use leases is as follows:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Net operating lease asset (included in Other property and equipment) | $ | $ | ||||||
| Current portion of lease liability | $ | $ | ||||||
| Long-term lease liability | ||||||||
| Total right-of-use lease liabilities | $ | $ | ||||||
The
weighted average remaining term for the Company’s right of use leases is years. The weighted average discount rate is
| 2025 | $ | ||||
| 2026 | |||||
| 2027 | |||||
| 2028 | |||||
| 2029 | |||||
| Thereafter | |||||
| Total lease payments | |||||
| Less: imputed interest | ( | ) | |||
| Total lease obligation | $ |
Note 9 – Equity
Pursuant to the Company’s Amended and Restated Certificate of Incorporation (“Charter”), effective as of March 4, 2022, the total number of shares of all classes of stock that the Company has the authority to issue is 200,000,000, consisting of shares of common stock, par value $ per share, and shares of preferred stock, par value $ per share.
Preferred Stock
Preferred stock may be issued from time to time in one or more series at the direction of the Company’s Board of Directors and the directors also have the ability to fix dividend rates and rights, liquidation preferences, voting rights, conversion rights, rights and terms of redemption and other rights, preferences, privileges and restrictions as determined by the Company’s Board of Directors, subject to certain limitations set forth in the Charter.
59
Series A Voting Preferred Stock
On March 8, 2022, the Company formalized the issuance of preferred stock as was required under the terms of the Company's May 2021 financing agreements with Energy Evolution and issued six shares of Series A Voting Preferred Stock. The Series A Voting Preferred Stock was issued in connection with the strategic investment in the Company by Energy Evolution. For so long as the Series A Voting Preferred Stock is outstanding, the Company’s Board of Directors will consist of six directors. Three of the directors are designated as the Series A Directors and the three other directors (each, a “common director”) are elected by the holders of common stock and/or any preferred stock (other than the Series A Voting Preferred Stock) granted the right to vote on the common directors. Any Series A Director may be removed with or without cause but only by the affirmative vote of the holders of a majority of the Series A Voting Preferred Stock voting separately and as a single class. The holders of the Series A Voting Preferred Stock have the exclusive right, voting separately and as a single class, to vote on the election, removal and/or replacement of the Series A Directors. Holders of common stock or other preferred stock do not have the right to vote on the Series A Directors. The approval of the holders of the Series A Voting Preferred Stock, voting separately and as a single class, is required to authorize any resolution or other action to issue or modify the number, voting rights or any other rights, privileges, benefits, or characteristics of the Series A Voting Preferred Stock, including without limitation, any action to modify the number, structure and/or composition of the Company’s current Board of Directors.
The
Series A Voting Preferred Stock is held by Phil Mulacek, Chairman of the Board of Directors of the Company and one of the principals
of Energy Evolution, as Energy Evolution’s designee (the “Initial Holder”). The Series A Voting Preferred Stock may
be transferred only to certain controlled affiliates of the Initial Holder (“Permitted Transferees”), and
The Series A Voting Preferred Stock is not entitled to receive any dividends or distributions of cash or other property except in the event of any liquidation, dissolution or winding up of the Company’s affairs. In such event, before any amount is paid to the holders of the Company’s common stock but after any amount is paid to the holders of the Company’s senior securities, the holders of the Series A Voting Preferred Stock will be entitled to receive an amount per share equal to $1.00.
Except as discussed above or as otherwise set forth in the certificate of designation of the Series A Voting Preferred Stock, the holders of the Series A Voting Preferred Stock have no voting rights.
The
Series A Voting Preferred Stock is not redeemable at the Company’s election or the election of any holder, except the Company may
elect to redeem
| · | any or all shares of Series A Voting Preferred Stock are held by anyone other than the Initial Holder or a Permitted Transferee; or |
| · | the Series A Holders together hold less than shares of the Company’s outstanding common stock. |
The Series A Voting Preferred Stock is not convertible into common stock or any other security.
Common Stock
On August 27, 2021, the Company’s Board of Directors approved a one-for-four reverse stock split such that every holder of the Company’s common stock would receive one share of common stock for every four shares owned. The reverse stock split was effective as of 6:00 p.m. Eastern Time on March 7, 2022, immediately prior to the Company’s listing of its common stock on the NYSE American. All share amounts have retrospectively been stated at post-reverse split amounts and pricing.
The holders of shares of common stock are entitled to one vote per share for all matters on which common stockholders are authorized to vote on. Examples of matters that common stockholders are entitled to vote on include, but are not limited to, the election of three of the six directors and other common voting situations afforded to common stockholders.
In
July 2023,
In
April 2024, Empire completed a subscription rights offering (the "April Rights Offering”) which raised gross proceeds of
$
60
On
May 31, 2024,
In
November 2024, Empire completed a subscription rights offering (the "November Rights Offering”) which raised gross proceeds
of $
See Note 14 for information regarding other transactions where shares of common stock of the Company were issued.
Empire recognizes stock-based compensation expense associated with granted stock options and restricted stock units ("RSUs”). Empire accounts for forfeitures of equity-based incentive awards as they occur. Stock-based compensation expense related to time-based restricted stock units is based on the price of the common stock on the grant date and recognized as vesting occurs. For options, the fair value is determined using the Black-Scholes option valuation assumptions on dividend yield, expected annual volatility, risk-free interest rate and an expected useful life. Stock-based compensation expense for restricted stock units and stock options is included in general and administrative expense in the consolidated statements of operations and is recorded with a corresponding increase in additional paid-in capital within the consolidated balance sheets.
On April 3, 2019, the Board of Directors of the Company adopted the Empire Petroleum Corporation 2019 Stock Option Plan (the “2019 Stock Option Plan”). The total number of shares of common stock that may be issued pursuant to stock options under the 2019 Stock Option Plan was . On August 27, 2021, the Board of Directors of the Company adopted the Company’s 2021 Stock and Incentive Compensation Plan (the “2021 Incentive Plan”) which was subsequently approved by stockholders of the Company. As a result of such approval, no further awards will be made under the 2019 Incentive Plan. The total number of shares of common stock that could be issued pursuant to the 2021 Incentive Plan is . On August 26, 2022, the stockholders of the Company approved the Company’s 2022 Stock and Incentive Compensation Plan (the “2022 Incentive Plan”) which reserves shares of the Company’s common stock for issuance thereunder. As a result of such approval, no further awards will be made under the 2021 Incentive Plan. On June 9, 2023, the stockholders of the Company approved the Company’s 2023 Stock and Incentive Compensation Plan (the “2023 Incentive Plan”) which reserves shares of the Company’s common stock for issuance thereunder. As a result of such approval, no further awards will be made under the 2022 Incentive Plan. On June 14, 2024, the Board of Directors adopted the Company’s 2024 Stock and Incentive Compensation Plan (the “2024 Incentive Plan”) which reserves 700,000 shares of the Company’s common stock for issuance thereunder. As a result of such approval no further awards will be made under the 2023 Incentive Plan. The 2024 Incentive Plan authorizes the grant of non-qualified stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards (restricted stock awards, restricted stock units, performance shares and performance units are collectively referred to as restricted stock units for purposes of this Note). At December 31, 2024, shares of our common stock were available for future grants.
Restricted Stock Units
Each RSU represents the contingent right to receive one share of common stock. The holders of outstanding RSUs do not receive dividends or have voting rights prior to vesting and settlement. The Company determines the fair value of granted RSUs based on the market price of the common stock on the date of the grant. Compensation expense for granted RSUs is recognized on a straight-line basis over the vesting and is net of forfeitures, as incurred.
RSUs
are generally granted with 12-month, 13-month, or 3-year service periods. Total value assigned to the RSUs granted in 2024 based on grant
date price approximated $
61
The following summary reflects nonvested restricted stock unit activity and related information:
| Weighted-Average | ||||||||
| Shares | Fair Value (1) | |||||||
| Outstanding, December 31, 2022 | $ | |||||||
| Granted | ||||||||
| Vested | ( | ) | ||||||
| Forfeited | ( | ) | ||||||
| Outstanding, December 31, 2023 | $ | |||||||
| Granted | ||||||||
| Vested | ( | ) | ||||||
| Forfeited | ( | ) | ||||||
| Outstanding, December 31, 2024 | $ | |||||||
| (1) |
| 2024 | ||||
| Weighted-Average grant date fair value of restricted stock units granted during the year, per share | $ | |||
| Total fair value of restricted stock units vested during the year | $ | |||
Stock Options
Each stock option award provides the opportunity in the future to purchase Empire common shares at the market price of our common stock on the date the award is granted (the strike price). The options generally become exercisable in equal amounts over a three-year vesting period or over one-year for options awarded to the Board of Directors of the Company; however, certain options become exercisable only if certain performance criteria are met. Stock options have no financial statement effect on the date they are granted but rather are reflected over time through recording stock-based compensation expense. The stock-based compensation expense is based on the estimated fair value of the awards expected to vest, and that amount is amortized as compensation expense on a straight-line basis over the respective vesting period and is net of forfeitures, as incurred.
The estimated fair value of an option is calculated using a Black-Scholes option valuation model with the following assumption inputs: dividend yield, expected annual volatility, risk free interest rate and an expected life of the option. The following table summarizes the weighted-average fair value and assumptions:
| 2024 | 2023 | |||||||
| Weighted-average grant-date fair value of stock options | $ | $ | ||||||
| Stock Options Valuation Assumptions: | ||||||||
| Risk-free interest rate | % | % | ||||||
| Dividend yield | % | % | ||||||
| Expected volatility | % | % | ||||||
| Expected option life (in years) | ||||||||
| Other pricing model inputs: | ||||||||
| Weighted average grant-date market prices of Empire stock (strike price) | $ | $ | ||||||
For
the years ended December 31, 2024 and 2023, approximately $ million and $ million of compensation expense related to stock options
was recognized. At December 31, 2024, approximately $
62
| Weighted-Average | ||||||||||
| Options | Exercise Price | |||||||||
| Outstanding, December 31, 2022 | $ | |||||||||
| Granted | ||||||||||
| Exercised | ( | ) | ||||||||
| Forfeited | ( | ) | ||||||||
| Outstanding, December 31, 2023 | $ | |||||||||
| Granted | ||||||||||
| Exercised | ( | ) | ||||||||
| Forfeited | ( | ) | ||||||||
| Outstanding, December 31, 2024 | $ | |||||||||
The following table summarizes information about stock options as of December 31, 2024:
| Range of Exercise Price | $ to $ | |||
| Weighted-Average Remaining Contractual Life | ||||
| Options Outstanding | ||||
| Options Exercisable | ||||
| Options Outstanding Aggregate Intrinsic Value | $ | |||
| Options Exercisable Aggregate Intrinsic Value | $ | |||
| Weighted-Average Outstanding Price | $ | |||
| Weighted-Average Exercise Price | $ | |||
Note 11 – Income Taxes
The following table represents the current and deferred income tax provisions:
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Current | $ | $ | ( | ) | ||||
| Deferred | ||||||||
| Income tax provision | $ | $ | ( | ) | ||||
At
December 31, 2024, the Company had approximately $
63
Deferred tax assets and liabilities are the result of temporary differences between the financial statement carrying values and the tax basis of assets and liabilities. The Company’s net tax position is as follows:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Deferred tax assets: | ||||||||
| Loss carry-forwards | $ | $ | ||||||
| Stock option grants | ||||||||
| Asset retirement obligation | ||||||||
| Other | ||||||||
| Total deferred tax assets | ||||||||
| Deferred tax liabilities: | ||||||||
| Oil and gas properties | ( | ) | ( | ) | ||||
| Other property and equipment | ( | ) | ( | ) | ||||
| Financial Derivatives | ( | ) | ||||||
| Lease liabilities | ( | ) | ( | ) | ||||
| Total deferred tax liabilities | ( | ) | ( | ) | ||||
| Net deferred tax asset before valuation allowance | ||||||||
| Valuation allowance | ( | ) | ( | ) | ||||
| Net deferred taxes | $ | $ | ||||||
Utilization of the Company’s loss carryforwards is dependent on realizing taxable income. The Company’s recorded valuation allowances of approximately $ million and $ million as of December 31, 2024 and 2023, respectively, are due to the uncertainty related to its ability to utilize some of its deferred income tax assets, primarily consisting of net operating loss carryforwards prior to expiration or the limitation under Section 382 as discussed above.
For
2024 and 2023, our effective tax rates were
The following table presents a reconciliation of its income tax (benefit) provision and effective income tax rate to the U.S. statutory income tax rate:
| For the Years Ended December 31, | ||||||||||||||||
| 2024 | 2023 | |||||||||||||||
| (Benefit) provision at statutory rate | $ | ( | ) | $ | ( | ) | ||||||||||
| State Taxes (net of federal impact) | ( | ) | ( | ) | ||||||||||||
| Nondeductible Expenses | ( | ) | - | |||||||||||||
| Return to Accrual | - | ( | ) | |||||||||||||
| Derivative Liability, Promissory Note Conversion | 314,660 | -1.9% | — | 0.0% | ||||||||||||
| NOLs Expected to Expire Unused Due to Section 382 Limitation | - | |||||||||||||||
| Valuation Allowance | - | - | ||||||||||||||
| Income tax (benefit) provision | $ | $ | ( | ) | ||||||||||||
The Company has evaluated all tax positions for which the statute of limitations remains open and believes that the material positions taken would more likely than not be sustained by examination. Therefore, at December 31, 2024, the Company has not established any reserves for, nor recorded any unrecognized benefits related to uncertain tax positions.
The Company’s only taxing jurisdiction is the United States. The Company’s tax years 2021 to present remain open for federal examination. Additionally, tax years 2004 through 2020 remain subject to examination for the purpose of determining the amount of federal NOL and other carryforwards. The number of years open for state tax audits varies, depending on the state, but is generally from three to five years.
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Diluted EPS gives effect to all dilutive potential common shares outstanding during the period. The computation of Diluted EPS does not assume conversion, exercise or contingent exercise of securities that would have an anti-dilutive effect on losses. As a result, if there is a loss from continuing operations, Diluted EPS is computed in the same manner as Basic EPS. In addition, approximately options were excluded in the current period Diluted EPS computation due to the option exercise price exceeding the weighted-average market price of our common shares.
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Net Loss | $ | ( | ) | $ | ( | ) | ||
| Basic Weighted-Average Shares | ||||||||
| Effect of Dilutive Securities: | ||||||||
| Restricted Stock Units and Stock Options (1) | ||||||||
| Diluted Weighted-Average Shares | $ | $ | ||||||
| Loss per Common Share | ||||||||
| Basic | $ | ( | ) | $ | ( | ) | ||
| Diluted | $ | ( | ) | $ | ( | ) | ||
| (1) |
Note 13 – Executive Management
On
March 16, 2023, Thomas W. Pritchard resigned as Chief Executive Officer and a director of the Company to pursue other opportunities.
Although not required under Mr. Pritchard’s Employment Agreement with the Company, in recognition of Mr. Pritchard’s past
service to the Company, the Company will pay Mr. Pritchard severance benefits in the amount of approximately $
On March 17, 2023, the Board of Directors of the Company appointed Michael R. Morrisett to the position of Chief Executive Officer. Mr. Morrisett did not receive any additional compensation for assuming the role of Chief Executive Officer.
In
July 2023, the Company’s Chief Operating Officer separated from the Company and received a severance of approximately $
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Note 14 – Related Party Transactions
Energy
Evolution is a related party of the Company as it beneficially owns approximately
In July 2023, Energy Evolution exercised its warrants for shares of common stock of the Company for $ per share. See Note 9 for additional information.
On
November 29, 2023,
On
November 29, 2023,
On
February 16, 2024, Empire issued the Note to Energy Evolution. Energy Evolution advanced Empire $
The
Company had a JDA with PIE to perform recompletion or workover on specified mutually agreed upon wells (See Note 7). In the third quarter
of 2024, Empire issued PIE 205,427 shares of common stock of Empire as payment in full for this outstanding note balance of $
In connection with the JDA, the Company also entered into a shared services agreement with PIE effective August 1, 2023, that includes access to administrative, engineering and support services as well as building and insurance services. The agreement provides that the Company will reimburse PIE for the out-of-pocket or actual costs incurred by PIE in providing such services to the Company.
Empire elected to partially exercise a purchase option in the second quarter of 2024 and acquired 60% of certain New Mexico interests from Energy Evolution. See Note 3 for additional information.
On
June 28, 2024, Energy Evolution exercised its warrants of Empire and received shares in exchange for approximately $
Accounts
receivable on the consolidated balance sheet include approximately $
Note 15 – Commitments and Contingencies
From time to time, the Company is subject to various legal proceedings arising in the ordinary course of business, including proceedings for which the Company may not have insurance coverage. While many of these matters involve inherent uncertainty, as of the date hereof, the Company does not currently believe that any such legal proceedings will have a material adverse effect on the Company’s business, financial position, results of operations or liquidity.
The Company is subject to extensive federal, state, and local environmental laws and regulations. These laws, among other things, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Management believes no materially significant liabilities of this nature existed as of the balance sheet date.
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Agreed Compliance Order
In
January 2024, the Company deposited $
New Mexico Trespass
In December 2023, the Company initiated a legal action in the Fifth Judicial District Court, Lea County, New Mexico, against a saltwater company for trespassing within one of the New Mexico water flood units. This suit is currently being pursued by Empire; however, the ultimate outcome of the litigation cannot be determined at this time, and no amount has been recognized due to the uncertainty of any conclusions that may arise as a result of such action.
Note 16 – Concentrations
The Company’s producing properties and oil and natural gas reserves are all located in Louisiana, New Mexico, North Dakota, Montana, and Texas. Because of the concentration, the Company is exposed to the impact of regional supply and demand factors, processing or transportation capacity constraints, severe weather events, water shortages, and government regulations specific to the geographic area.
For
the year ended December 31, 2024, the Company sold
The Company’s cash balances may at times exceed Federal Deposit Insurance Corporation (“FDIC”) insurance limits. The Company maintains cash accounts at reputable financial institutions.
Note 17 – Fair Value Measurements
The following table provides the carrying value and fair value measurement information for certain financial assets and liabilities. The carrying values of cash, accounts receivable, inventory, accounts payable, accrued expenses, lease liabilities, and equipment and vehicle notes included in the accompanying consolidated balance sheets approximated fair value at December 31, 2024 and December 31, 2023, as applicable, and generally represent Level 2 fair values due to their short-term nature. Therefore, such financial assets and liabilities are not presented in the following table:
| Fair Value Measurements Using: | ||||||||||||||||||||
| Carrying | Total Fair | Level 1 | Level 2 | Level 3 | ||||||||||||||||
| Amount | Value | Inputs | Inputs | Inputs | ||||||||||||||||
| December 31, 2024 assets (liabilities) | ||||||||||||||||||||
| Derivative instruments | $ | $ | $ | $ | $ | |||||||||||||||
| Debt - Credit Facility | ( | ) | ( | ) | ( | ) | ||||||||||||||
| Debt - Promissory Note, Related Party | ||||||||||||||||||||
| December 31, 2023 assets (liabilities) | ||||||||||||||||||||
| Derivative instruments | ||||||||||||||||||||
| Debt - Credit Facility | ( | ) | ( | ) | ( | ) | ||||||||||||||
| Debt - Promissory Note, Related Party | ( | ) | ( | ) | ( | ) | ||||||||||||||
The following methods and assumptions were used to estimate the fair values in the table above and other fair value measurements.
Level 2
Derivatives – Derivative financial instruments are carried at fair value and measured on a recurring basis. The Company’s commodity price hedges are valued based on discounted future cash flow models that are primarily based on published forward commodity price curves.
The fair values of derivative instruments in asset positions include measures of counterparty nonperformance risk, and the fair values of derivative instruments in liability positions include measures of the Company’s nonperformance risk. These measurements were not material to the consolidated financial statements.
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Debt – The fair value of our Credit Facility variable rate debt approximates the carrying value as the underlying prime rate changes based on prevailing market rates. The fair value of the promissory note prior to when the conversion was triggered was determined using a discounted cash flow model. See below for discussion on the fair value determination of the promissory note once conversion occurred.
Level 3
Impairment of oil and natural gas properties – The fair value of proved and unproved oil and natural gas properties was measured using valuation techniques that convert the future cash flows to a single discounted amount. Significant inputs to the valuation of proved and unproved oil and natural gas properties include estimates of: (i) recoverable reserves; (ii) production rates; (iii) future operating and development costs; (iv) future commodity prices; and (v) a market-based weighted-average costs of capital. The Company utilized a combination of the New York Mercantile Exchange strip pricing and consensus pricing to value the reserves, then applied various discount rates depending on the classification of reserves and other risk characteristics. For significant acquisitions, management utilized the assistance of a third-party valuation expert to estimate the value of the oil and natural gas properties acquired.
Asset Retirement Obligation – The fair value of AROs is included in proved oil and natural gas properties with a corresponding liability. The fair value was determined based on a discounted cash flow model, which included assumptions of the estimated current abandonment costs, discount rate, inflation rate and timing associated with the incurrence of these costs.
The inputs used to value oil and natural gas properties for impairments and asset retirement obligations require significant judgment and estimates made by management and represent Level 3 inputs.
Empire applies the provisions of fair value measurement on a non-recurring basis to its non-financial assets and liabilities, including oil and gas properties and asset retirement obligations. These assets and liabilities are not measured at fair value on an ongoing basis but are subject to fair value adjustments if events or changes in certain circumstances indicate that adjustments may be necessary. No triggering events that require assessment of such items were observed during the years ended December 31, 2024 and 2023.
Assets and Liabilities Measured at Fair Value on a Recurring Basis – In the determination of the fair value of the promissory note including the embedded conversion feature, Empire uses a binomial lattice valuation model to value Level 3 derivative liabilities at inception and on subsequent valuation dates. This model incorporates transaction details such as Empire’s stock price, contractual terms of the promissory note, and unobservable inputs classified as Level 3 including risk-free rate and expected volatility. Due to the subjective nature of these inputs, the fair value measurement could differ materially under alternative assumptions. As of the conversion option exercise date of May 24, 2024, these unobservable inputs were 5.0% and 46.9%, respectively.
Note 18 – Segment Reporting
The Company’s operations are managed and reported to its CEO, the Company’s CODM, on a consolidated basis. The CEO uses consolidated net loss in assessing performance of capital spend projects to allocate the appropriate resources to drive efficiencies and develop growth strategies. Under the organizational and reporting structure, the Company has one operating segment and one reportable segment.
The CODM is provided with the following significant segment expenses within lease operating expense on the consolidated statements of operations:
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Production costs | $ | $ | ||||||
| Workover activity | ||||||||
| Plugging and abandonment activity | ||||||||
| Lease operating expense | $ | $ | ||||||
Other segment items within consolidated net loss are all separately disclosed on the consolidated statements of operations. Segment asset information is not presented to and used by the CODM to allocate resources, assess performance or make strategic decisions.
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Note 19 – Supplemental Information of Oil and Natural Gas Producing Activities (Unaudited)
The following reserve estimates present the Company's estimate of the proven natural gas and oil reserves and net cash flow of the Company’s properties, in accordance with the guidelines established by the Securities and Exchange Commission. The Company emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries are more imprecise than those of producing natural gas and oil properties. Accordingly, the estimates are expected to change as future information becomes available. All the oil and natural gas reserves are located in Louisiana, New Mexico, North Dakota, Montana and Texas.
Costs Incurred Related to Oil and Gas Activities
Costs incurred include capitalized costs of properties, equipment, and lease facilities for oil and natural gas producing activities.
| For the Years Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| Acquisition | $ | $ | ||||||
| Exploration | ||||||||
| Development | ||||||||
| Total costs incurred | $ | $ | ||||||
Reserve Quantity Information
Proved oil and natural gas reserves are those quantities of oil and gas, which by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations. Proved developed reserves are proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well. Proved undeveloped reserves are proved reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. The information below excludes proved undeveloped reserves. Below are the net quantities of net proved developed reserves of the Company’s properties:
| Oil (MBbls) | Gas (MMcf) | NGLs (MBbls) | MBoe | ||
| Balance, December 31, 2022 | |
|
|
| |
| Acquisition of Reserves | |
|
|
| |
| Revisions | ( |
( |
( |
( | |
| Extensions | |
| |||
| Production | ( |
( |
( |
( | |
| Balance, December 31, 2023 | |
|
|
| |
| Acquisition of Reserves | |||||
| Revisions | ( |
|
|
| |
| Extensions | |||||
| Production | ( |
( |
( |
( | |
| Balance, December 31, 2024 |
The acquisition of reserves for 2024 and 2023 primarily relate to additional working interests in certain of the Company’s New Mexico properties (See Note 3) during the respective periods. The revisions for the respective periods primarily relate to changes in pricing and the extensions relate to increased volumes from our Starbuck Drilling Program.
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Standardized Measure of Discounted Future Net Cash Flows Relating to Oil and Natural Gas Reserves
The standardized measure of discounted future net cash flows relating to oil and natural gas reserves and associated changes in standard measure amounts were prepared in accordance with the provision of FASB ASC 932-235-555, Extracting Activities – Oil and Gas (“Topic 932”). Future cash inflows were computed by applying average prices of oil and natural gas for the last 12 months to estimated future production. Future production and development costs were computed by estimating the expenditures to be incurred in developing the oil and natural gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions. Future net cash flows are discounted at the rate of 10% annually to derive the standardized measure of discounted cash flows. Actual future cash inflows may vary considerably, and the standardized measure does not necessarily represent the fair value of the acquired properties' oil and natural gas reserves. Standard measure amounts are:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Future cash inflows | $ | $ | ||||||
| Future production costs | ( | ) | ( | ) | ||||
| Future development costs | ( | ) | ( | ) | ||||
| Future income tax expense | ( | ) | ( | ) | ||||
| Future net cash flows | ||||||||
| 10% annual discount for estimated timing of cash flows | ( | ) | ( | ) | ||||
| Standardized measure | $ | $ | ||||||
The 12-month average prices were adjusted to reflect applicable transportation and quality differentials on a well-by-well basis to arrive at realized sales prices used to estimate the properties' reserves. The prices for the properties' reserves were as follows:
| 2024 | 2023 | |||||||
| Oil (BBl) | $ | $ | ||||||
| Natural gas (MMBtu) | $ | $ | ||||||
| NGLs (BBl) | $ | $ | ||||||
Changes in the Standardized Measure of Discounted Future Net Cash Flows at 10% per annum are as follows:
| As of December 31, | ||||||||
| 2024 | 2023 | |||||||
| Beginning of year | $ | $ | ||||||
| Net change in prices and production costs | ( | ) | ( | ) | ||||
| Net change in future development costs | ||||||||
| Oil & Gas net revenue | ( | ) | ( | ) | ||||
| Extensions | ||||||||
| Acquisition of reserves | ||||||||
| Revisions of previous quantity estimates | ( | ) | ||||||
| Net change in taxes | ||||||||
| Accretion of discount | ||||||||
| Changes in timing and other | ( | ) | ||||||
| End of year | $ | $ | ||||||
Estimates of economically recoverable natural gas and oil reserves and of future net revenues are based upon a number of variable factors and assumptions, all of which are to some degree subjective and may vary considerably from actual results. Therefore, actual production, revenues, development and operating expenditures may not occur as estimated. The reserve data are estimates only, are subject to many uncertainties, and are based on data gained from production histories and on assumptions as to geologic formations and other matters. Actual quantities of natural gas and oil may differ materially from the amounts estimated.
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