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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)
_________________
| (State or Other Jurisdiction | (I.R.S. Employer | |
| of Incorporation or Organization) | Identification No.) |
(Address of Principal Executive Offices) (Zip Code)
Registrant's telephone number, including area code: (
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
Securities registered pursuant to 12(g) of the Act:
None
(Title of class)
_________________
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
☐
Yes ☑
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
☐
Yes ☑
Indicate 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 Act of 1934 during the preceding 12 months (or for such shorter
period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☑
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Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
☑
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 | |
| 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. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).
☐
Yes ☑
The aggregate market value of the voting and non-voting common equity
held by non-affiliates, computed by reference by the average bid and asked 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 15, 2022 was .
DOCUMENTS INCORPORATED BY REFERENCE
None.
-2-
EMPIRE PETROLEUM CORPORATION
FORM 10-K
TABLE OF CONTENTS
-3-
FORWARD-LOOKING STATEMENTS
Certain statements in this Annual Report on Form 10-K constitute “forward-looking statements” within the meaning of 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 the Company’s website or otherwise, in the future by us or on our behalf. Such statements are generally identifiable by the terminology used such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecasted,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “project,” “should,” “would” or other similar words, although not all forward-looking statements contain such identifying words.
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 statements. Such factors include, among others: general economic conditions; management’s ability to execute the Company’s business plan; changes in oil, natural gas and natural gas liquids prices and the demand for oil, natural gas and natural gas liquids; the Company’s ability to replace reserves and efficiently develop current reserves; costs of operations; 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 from future cash flows, available borrowing capacity under revolving credit facilities and otherwise; management’s ability to make acquisitions on economically acceptable terms; management’s ability to integrate acquisitions; weather and environmental conditions; and the other factors discussed below and elsewhere in this Form 10-K and in other documents that we file with or furnish to the United States Securities and Exchange Commission (the “SEC”), all of which are difficult to predict. Factors that could cause results to differ materially from the results discussed in such forward-looking statements include:
| - | the need for additional capital, |
| - | unforeseen engineering, mechanical or technological difficulties in working over wells, |
| - | operating hazards, |
| - | competition from other natural resource companies, |
| - | the fluctuations of prices for oil, natural gas, and natural gas liquids, |
| - | unanticipated reductions in the borrowing base under the credit agreement 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 ESG 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 world health events, including the coronavirus pandemic (“COVID-19”), |
| - | the effects of governmental and environmental regulation, and |
| - | general economic conditions and other risks described in the Company's filings with the Securities and Exchange Commission (the "SEC"). |
All forward-looking statements are expressly qualified in their entirety by the cautionary statements in this section and elsewhere in this Annual Report on Form 10-K. Other than as required by applicable securities laws, we do not assume a 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 pace 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 CERTAIN OIL AND NATURAL GAS TERMS
The following are abbreviations and definitions of terms commonly used in the oil and natural gas industry and within this report.
Bbl – One barrel or 42 U.S. gallons liquid volume of oil or other liquid hydrocarbons.
Bcf – One billion cubic feet of natural gas.
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.
CGA – Cawley, Gillespie Associates, Inc.
DDA – Depreciation, depletion and amortization.
ESG – Environmental, Social and Governance.
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.
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.
Net acres or net wells – The sum of the fractional working interests owned in gross acres or gross wells.
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.
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 NGL 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 PA – 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.
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.
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.
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 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 well to restore or increase production.
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PART I
ITEM 1. BUSINESS.
In this Form 10-K, references to “Empire”, the “Company”, “we”, and “our” refer to Empire Petroleum Corporation and its wholly-owned subsidiaries, unless context indicates otherwise.
The Company uplisted from the OTCQB to the NYSE American effective March 8, 2022. Immediately prior to the listing, a reverse stock split of 1 for 4 occurred. All pricing and share amounts have been stated at post-reverse split amounts.
On March 8, 2022, the Company’s common stock began trading on the New York Stock Exchange American (“NYSE American”) under the symbol “EP” and CUSIP 292034303. Prior to trading on the NYSE American, the Company’s common stock was accessible on the OTCQB.
Overview
Empire Petroleum Corporation is an independent energy company owner-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 North Dakota LLC (“Empire North Dakota”) |
| · | Empire New Mexico LLC d/b/a Green Tree New Mexico (“Empire New Mexico”) |
| · | Empire Texas (“Empire Texas”), consisting of the following entities: |
| o | Empire Texas LLC |
| o | Empire Texas GP LLC |
| o | 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 Utah in August 1983 and subsequently 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 Company’s mission is to increase shareholder value by building oil and natural gas reserves in strategic plays in the United States. To accomplish its mission, the Company plans on executing the following business strategies:
| · | Target proved developed producing acquisitions in predictable, fields that have historically had low decline and long lives |
| · | Focus on high-quality assets that add scale and provide synergies to the Company’s existing portfolio and core areas of operation |
| · | Cost-effectively optimize well production by deploying rigorous field management programs |
| · | Reduce unit operating costs and improve margins by utilizing experienced field personnel |
The Company operates as a single segment as each of its operating areas has similar economic characteristics and each meet the criteria for aggregation as defied by accounting standards related to disclosures about segments of an enterprise.
The Company has progressed through several leadership teams since its inception in 1983 and the most recent management team was installed in 2017 and its first PDP operating assets were purchased in 2018.
Properties
The Company is an independent operator in four geographic areas in the United States. As operator, the Company manages and influences production on operated properties. The Company uses a combination of experienced field personnel and third-party service providers to execute its mission. The Company’s properties have reasonably predictable production profiles and cash flows, subject to commodity price and cost fluctuations.
As is common in the industry in which the Company operates, the Company selectively participates in drilling and developmental activities in non-operated properties. Decisions to participate in non-operated properties are dependent upon the technical and economic nature of the projects and the operating expertise and historical track record of the operators.
Empire Louisiana
Empire Louisiana acquired its assets in late 2018 and has 11 producing properties and three saltwater disposal wells in the following formations:
| · | Miocene |
| · | Frio |
| · | Cockfield |
| · | Wilcox |
Empire Louisiana’s assets primarily produce oil from properties with average WI of 58% and NRI of average operated NRI of 47%.
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Empire New Mexico
Empire New Mexico was formed when the Company purchased producing assets from XTO in May 2021. These assets are located in Lea County, New Mexico and consist of a contiguous and consolidated acreage position consisting of 48,000 gross (40,000 net) acres held by production from approximately 730 wells with an average WI of 72% and average NRI of 61% and 14 RI wells with an average ORRI of 11% Empire New Mexico’s assets primarily produce oil with natural gas and NGLs accompanying oil production. Empire New Mexico’s properties are in the following formations:
| · | Grayburg/San Andres (primary source of production) |
| · | Queen-Seven Rivers-Yates |
| · | Devonian |
| · | Abo |
| · | Blinebry |
| · | Tubb |
| · | Drinkard |
Empire North Dakota
Empire North Dakota operates approximately 230 producing properties with an average WI of 89% and NRI of 61% in North Dakota and western Montana that were acquired in April 2019. These properties primarily produce oil with some related gas production. Assets are located in the following formations:
| · | Madison (primary source of production) |
| · | Bakken |
| · | Duperow |
| · | Red River |
| · | Ratcliffe/Mission Canyon |
Presence in these formations allows the Company to execute its mission in areas with sustained impressive, near-flat production rates over the last five years and capitalize on operational improvements to allow more immediate recovery of reserves.
Empire Texas
In April 2020, Empire Texas acquired 139 gross wells and approximately 30,000 net acres with an average operated WI of 96% and an average operated NRI of 79% 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.
In August 2020, Empire Texas entered into a joint development agreement with Petroleum Independent Exploration, LLC and related entities (“PIE”). Under the terms of this agreement, PIE will perform recompletion or workover on specified mutually agreed upon wells (“Workover Wells”) owned by Empire Texas. To fund the work, PIE entered into a term loan agreement with the Company dated August 1, 2020, whereby PIE will loan up to $2,000,000, at an interest rate of 6% per annum, maturing August 7, 2024 unless terminated earlier by PIE. Proceeds of the loan will be used for recompletion or workover of the Workover Wells. Empire Texas will assign a combined 85% working and revenue interest in the Workover Wells to PIE when work commences on a property. Of the assigned interest, 70% working and revenue interest will be used to repay the obligations under the term loan agreement. Once the term loan is repaid, PIE will reassign a 35% working and revenue interest to Empire Texas in each of the Workover Wells and retain a 50% working and revenue interest.
-7-
Production and Operating Data
The following table sets forth a summary of our production and operating data for the years ended December 31, 2021 and 2020. 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.
Year ended December 31, 2021 | Year ended December 31, 2020 | |||||||
| Production and operating data: | ||||||||
| Net production volumes: | ||||||||
| Oil (Bbl) | 333,158 | 164,869 | ||||||
| Natural gas (Mcf) | 622,474 | 139,412 | ||||||
| Natural gas liquids (gal) | 4,321,497 | — | ||||||
| Total (Boe) | 539,796 | 188,104 | ||||||
| Average price per unit: | ||||||||
| Oil (a) | $ | 64.52 | $ | 42.00 | ||||
| Natural gas (a) | $ | 3.90 | $ | 2.53 | ||||
| Natural gas liquids | $ | 0.79 | $ | — | ||||
| Total (Boe) | $ | 50.61 | $ | 38.68 | ||||
| Operating costs and expenses per Boe: | ||||||||
| Oil and natural gas production | $ | 26.11 | $ | 25.90 | ||||
| Production and ad valorem taxes | $ | 3.90 | $ | 1.84 | ||||
| Depreciation, depletion, amortization and accretion | $ | 6.89 | $ | 21.52 | ||||
| Impairment | $ | — | $ | 46.10 | ||||
| General administrative | $ | 15.68 | $ | 39.20 | ||||
| (a) | Includes the effect of net cash receipts (payments on) derivatives, as applicable contracts are in place. |
At December 31, 2021, the Company has approximately 1,100 operated wells. At December 31, 2020, the Company had 190 producing wells of which it operated 156.
The Company has no operated wells in process as of December 31, 2021, or 2020 and had no drilling activity during the year with the exception of four non-operated wells.
The Company has no delivery commitments for oil or natural gas.
Oil and Natural Gas Reserves
The Company engaged an independent petroleum engineering firm, CGA, to prepare its annual reserve estimates and has relied on CGA’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 CGA since 1989 and graduated from Texas AM 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 and The Society of Petroleum Evaluation Engineers.
Brian Weatherl, Vice President of Engineering, is responsible for reservoir engineering, and is a qualified reserve estimator and is responsible for overseeing CGA during the preparation of the annual reserve estimates. His professional qualifications meet or exceed the qualifications of reserve estimators set forth in the “Standards Pertaining to Estimation and Auditing of Oil and Natural Gas Reserve Information” promulgated by the Society of Petroleum Engineers. His qualifications include a Bachelor of Science degree in Petroleum Engineering from the University of Tulsa in 1984 and he is a member of the Society of Petroleum Engineers. Mr. Weatherl has been estimating and evaluating reserves for over 35 years.
The Company maintains adequate and effective internal controls over the reserves estimation process as well as the underlying data upon which reserve estimates are based. 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 CGA has technical meetings with Company personnel. Current revenue and expense information is obtained from accounting records, which are subject to external quarterly reviews, annual audits, and internal controls over financial reporting. Internal controls over financial reporting are assessed for effectiveness annually using criteria set forth in “Internal Control – Integrated Framework” (2013 version) issued by the Committee of Sponsoring Organizations of the Treadway Commission. All current financial data such as commodity prices, lease operating expenses, production taxes and field level commodity price differentials are updated in the reserve database and then analyzed to ensure that they have been entered accurately and that all updates are complete. The Company’s ownership in mineral interests and well production data are subject to internal controls and are incorporated into the reserve database as well as verified internally by Company personnel to ensure accuracy and completeness. Once the reserve database has been updated with current information, and the relevant technical support material has been assembled, CGA meets with technical personnel to review field performance and future development plans in order to verify the validity of estimates. Following these reviews, the reserve database is furnished to CGA so that it can prepare its independent reserve estimate and final report. The reserve estimates prepared by CGA are reviewed and compared to internal estimates by Mr. Weatherl. Material reserve estimation differences are reviewed between CGA and Company personnel and additional data is provided to address any variances. If the supporting documentation does not justify additional changes, CGA reserves are accepted. In the event that additional data supports a reserve estimation adjustment, CGA will analyze the additional data and may make changes it solely deems necessary. Additional data is usually comprised of updated production information on new wells. Once the review is completed and all material differences are reconciled the reserve report is finalized and our reserve database is updated with the final estimates provided by CGA.
Net proved reserves were calculated using flat, twelve-month average commodity index prices for each month 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 $64.31 per barrel and $7.34 per Mcf were utilized at December 31, 2021. Natural gas pricing includes prices received for NGLs during the year. Due to the inherent uncertainty associated with estimating NGLs, no NGL volumes were included in the reserve report.
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The following table represents the Company’s oil and natural gas reserves at December 31, 2021.
| Oil | Natural Gas | ||
| (Mbbl) | (MMcf) | ||
| Proved developed | 8,448 | 11,205 |
The following table represents the Company’s oil and natural gas reserves at December 31, 2020. Pricing was in accordance with SEC guidelines and was $32.94 per barrel and $1.41 per Mcf.
| Oil | Natural Gas | ||
| (Mbbl) | (MMcf) | ||
| Proved developed | 3,331 | 940 |
The Company’s primary mission is to optimize existing producing properties; as such, there are no reserves estimated for undeveloped properties, though the Company owns acreage that can be drilled in the future and is also a non-operator WI owner on acreage subject to future drilling activities.
Reserve engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that 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. The quantities of oil and natural gas that are ultimately recovered, production and operating costs, and future oil and natural gas prices may differ from those assumed in these estimates. Our internal professionals work closely with the Company’s external engineers to ensure the integrity, accuracy, and timeliness of data that is furnished to them for their reserve estimation process.
COVID-19
Despite recoveries in commodity prices, recent surges from COVID-19 variants continue to impact the global economy, disrupt global supply chains, and have the potential to create significant volatility and disruption of financial and commodity markets. The extent of the impact of the COVID-19 pandemic on the Company’s operational and financial performance, including its ability to execute business strategies and initiatives in the expected timeframes, is uncertain and depends on various factors, including how the pandemic and measures taken in response to its effects impact the demand for oil and natural gas, the availability of personnel, equipment, and services critical the Company’s ability to operate its properties and the impact of potential governmental restrictions. There is uncertainty regarding the extent and duration of any disruption.
As a producer of oil, natural gas, and NGLs, the Company is recognized as an essential business under various federal, state, and local regulations related to the COVID-19 pandemic. The Company has continued to operate as permitted while working to protect the health and safety of employees.
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 natural gas liquids under purchase contracts using market-based pricing, which is sold at the lease location.
Principal Customers
We sell our oil, natural gas, and NGL 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 2021, 63% revenues from oil, natural gas, and NGL sales were to four customers. For 2020, revenues from oil and natural gas sales to four customers accounted for 95% of our total operating revenues. 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 region.
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 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.
-9-
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 fluctuation, results of operations for individual quarterly periods may not be indicative of the results realized on an annual basis.
Markets; Price Volatility
The market price of oil and gas is volatile, subject to speculative movement and depends upon numerous factors beyond the control of the Company, 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 gas. If the market price for oil and gas remains depressed in the future, it could have a material adverse effect on the Company's ability to raise additional capital necessary to finance operations. Lower oil and gas prices may also reduce the amount of oil and gas, if any, that can be produced economically from the Company's properties. The Company anticipates that the prices of oil and gas will fluctuate in the near future.
Regulation
The oil and 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 gas industry is constantly changing. Numerous federal and state departments and agencies have issued rules and regulations applicable to the oil and 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 gas resources; and, in some cases, rates of production. The heavy and increasing regulatory burdens on the oil and gas industry increase the Company's cost of doing business and, consequently, affect profitability.
The oil and 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 the Company fails to comply or if any contamination results from the Company's operations.
Employees
At December 31, 2021, the Company had thirty-one full-time employees, not including contract personnel and outsourced service providers. The Company’s 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, OK, with field offices in North Dakota, Texas, and New Mexico.
ITEM 1A. RISK FACTORS.
The Company’s 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 operations or financial position. Risks and uncertainties discussed below are not a comprehensive listing of those faced by the Company. Additional risks not presently known or that are deemed immaterial may also affect the Company. 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.
-10-
Reserves
The Standardized Measure and PV-10 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. Our non-GAAP (Generally Accepted Accounting Principles) financial measure, PV-10, is a similar reporting convention that we have disclosed in this report. Both measures require the use of operating and development costs prevailing as of the date of computation. Consequently, they 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 it reflect the actual costs that will be required to produce or develop the oil and natural gas properties. Accordingly, estimates included herein 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 our company or the oil and natural gas industry in general.
Therefore, Standardized Measure and PV-10 included in this report should not be construed as accurate estimates of the current fair value of proved reserves.
Estimates of proved reserves and future net cash flows are not precise. The actual quantities of 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 and remedial costs. |
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.
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 and natural gas; and |
| - | changes in governmental regulations or taxation. |
Accordingly, estimates included herein 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.
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Unless reserves are replaced, production and estimated reserves will decline, which may adversely affect the Company’s 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 the Company’s success in efficiently developing and exploiting current properties and economically finding or acquiring additional recoverable reserves. The Company may not be able to develop, find or acquire additional reserves to replace its current and future production at acceptable costs. If the Company is unable to replace our current and future production, cash flows and the value of reserves may decrease, adversely affecting the Company’s business, financial condition and results of operations.
Financing
The Company has indebtedness and may incur substantially more debt. Higher levels of indebtedness make the Company more vulnerable to economic downturn and adverse business developments.
The Company’s subsidiaries Empire Louisiana and Empire North Dakota had approximately $7.1 million of outstanding aggregate principal indebtedness at December 31, 2021. At December 31, 2021, commitments from our financial institution (as amended) were $7.4 million, of which approximately $300,000 was unused commitments. Management continues to review existing indebtedness, and may seek to repay, refinance, repurchase, redeem, exchange or otherwise terminate our indebtedness. If the Company does 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, the Company uses a portion of its 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 the Company operates. Indebtedness under the Credit Facility is at a variable interest rate, and so a rise in interest rates will generate greater interest expense.
The Company may incur substantially more debt in the future. The Credit Facility contains restrictions on incurrence of additional indebtedness.
Increases in the level of indebtedness could have adverse effects on the Company’s 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; |
| - | 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. |
The Company’s ability to meet its debt obligations and reduce its 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.
The 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 partially through borrowings under the Credit Facility. 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 the Company is 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; |
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| - | 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 the Company’s credit ratings; and |
| - | proved reserves. |
The Company 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 the Company’s 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 the Company’s 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 the Company’s 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.
If the Company is unable to comply with the covenants in its debt agreement, there could be a default under the terms of the agreement, which could result in an acceleration of payment of funds that we have borrowed.
The Company’s ability to meet its 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, 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 our Senior Revolver Loan Agreement to avoid being in default. If we breach our covenants and cannot obtain a waiver from the required lenders, we would be in default and the lenders could exercise their rights, as described above, and we could be forced into bankruptcy or liquidation.
A negative shift in stakeholder sentiment towards the oil and 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 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 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.
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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. 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.
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 the ongoing impact of COVID-19; |
| - | the price and quantity of imports of foreign oil and natural gas; |
| - | political conditions, including 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; |
| - | 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. The recent volatility in the price of oil has forced the Company, 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 the Company and its 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, 2021, 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 this area 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.
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The Company's insurance policies may not adequately protect the Company against certain unforeseen risks.
In accordance with customary industry practice, the Company maintains insurance against some, but not all, of the risks described herein. There can be no assurance that any insurance will be adequate to cover the Company's losses or liabilities. The Company cannot predict the continued availability of insurance, or its availability at premium levels that justify its purchase.
The Company is subject to various environmental risks, and governmental regulation relating to environmental matters.
The Company is 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 the Company 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 the Company's financial condition or results of operations, there can be no assurance that the Company will not be required to make material expenditures in the future. Moreover, the Company anticipates that such laws and regulations will become increasingly stringent in the future, which could lead to material costs for environmental compliance and remediation by the Company. Any failure by the Company to obtain required permits for, control the use of, or adequately restrict the discharge of hazardous substances under present or future regulations could subject the Company to substantial liability or could cause its operations to be suspended. Such liability or suspension of operations could have a material adverse effect on the Company's business, financial condition and results of operations.
The Company's activities are subject to extensive governmental regulation. Oil and 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 gas. In addition, the production, handling, storage, transportation and disposal of oil and gas, by-products thereof and other substances and materials produced or used in connection with oil and 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 the operations of the Company. There can be no assurance that the trend of more expansive and stricter environmental legislation and regulations will not continue.
As a result of previous low prices for oil, natural gas and NGL, 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.
We periodically assess our properties for impairment based on future estimates of proved and non-proved 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 NGL 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
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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 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.
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 NGL exploration and production activities, and reduce demand for the oil, natural gas and NGL 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 CAA, the EPA has adopted regulations that, among other things, establish construction and operating permit reviews for 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, and together with the DOT, implement GHG emissions limits on vehicles manufactured for operation in the United States. The federal regulation of methane from oil and gas facilities has been subject to uncertainty in recent years. In November 2021, the EPA proposed new regulations to establish comprehensive standards of performance and emission guidelines for methane and volatile organic compound emissions from existing operations in the oil and gas sector, including the exploration and production, transmission, processing, and storage segments. The EPA is currently seeking public comments on its proposal, which the EPA hopes to finalize by the end of 2022. Once finalized, the regulations will also need to be incorporated in state implementation plans and approved by EPA. However, all of these regulatory actions will likely be subject to legal challenges. 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 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. 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
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sustainable lending practices and some of them may elect not to provide funding for fossil fuel energy companies. For example, at COP26, the Glasgow Financial Alliance for Net Zero (“GFANZ”) announced that commitments from over 450 firms across 45 countries had resulted in over $130 trillion in capital committed to net zero goals. The various sub-alliances of GFANZ generally require participants to set short-term, sector-specific targets to transition their financing, investing, and/or underwriting activities to net zero emissions by 2050. There is also a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. 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. More recently, in November 2021, the Federal Reserve issued a statement in support of the efforts of the NGFS to identify key issues and potential solutions for the climate-related challenges most relevant to central banks and supervisory authorities. 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.
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.
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 damages 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 NGL 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.
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Because we cannot control activities on properties we do not operate, we cannot directly control the timing of exploitation. 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.
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 expenditures associated with the project. If we are not willing or able to fund required capital expenditures relating toa 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.
The Company could be adversely affected by increased costs of service providers utilized by the Company.
In accordance with customary industry practice, the Company has 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 the Company's production costs.
Our ability to use our existing net operating loss carryforwards or other tax attributes could be limited.
At December 31, 2021, we had approximately $20.7 million of federal NOL carryforwards available to offset against future taxable income. Utilization of any NOL depends on many factors, including our ability to generate future taxable income, which cannot be assured.
Legislation
Climate change legislation, regulations restricting emissions of “greenhouse gases” (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.
In response to findings that emissions of carbon dioxide, methane and other greenhouse gases present an endangerment to public health and the environment, the EPA has issued regulations to restrict emissions of GHGs under existing provisions of the CAA. These regulations include limits on tailpipe emissions from motor vehicles and preconstruction and operating permit requirements for certain large stationary sources. The EPA has also adopted rules requiring the reporting of GHG emissions from specified large GHG emission sources in the United States, as well as certain onshore oil and natural gas production facilities, on an annual basis, including GHG emissions resulting from the completion and workover operations of hydraulically fractured oil wells. Recent federal regulatory action with respect to climate change has focused on methane emissions. For example, in June 2016, the EPA finalized new air emission controls for emissions of methane from certain equipment and processes in the oil and natural gas source category, including production, processing, transmission and storage activities. The final rule package includes first-time standards to address emissions of methane from equipment and processes across the source category, including hydraulically fractured oil and natural gas well completions, and also imposes leak detection and repair requirements on operators. However, in June 2017, the EPA proposed a two year stay of fugitive emissions monitoring requirements, pneumatic pump standards, and closed vent system certification requirements in the 2016 rule while it reconsiders these aspects of the rule. Additionally, on September 11, 2018, the EPA proposed targeted improvements to the 2016 rule, including amendments to the rule’s fugitive emissions monitoring requirements, and expects to “significantly reduce” the regulatory burden of the rule in doing so. The BLM finalized similar rules in November 2016 that limit methane emissions from new and existing oil and natural gas operations on federal lands through limitations on the venting and flaring of gas, as well as enhanced leak detection and repair requirements but then finalized a revised rule in 2018 which scaled back the waste prevention requirements of the 2016 rule. Environmental groups have sued in federal district court to challenge the legality of aspects of the revised rule, and the outcome of this litigation is currently uncertain. These methane emission rules have the potential to increase our compliance costs.
While Congress has from time to time considered legislation to reduce emissions of GHGs, there has not been significant activity in the form of adopted legislation to reduce emissions of GHGs in recent years. In the absence of Congressional action, many states have established rules aimed at reducing GHG emissions, including GHG cap and trade programs. Most of these cap-and-trade programs work by requiring major sources of emissions, such as electric power plants, or major producers of fuels, such as refineries and natural gas processing plants, to acquire and surrender emission allowances. The number of allowances available for purchase is reduced each year in an effort to achieve the overall GHG emission reduction goal. In the future, the United States may also choose to adhere to international agreements targeting GHG reductions.
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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 the Company is 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.
The Company does not expect to declare or pay any dividends in the foreseeable future.
The Company has not declared or paid any dividends on its Common Stock. The Company currently intends to retain future earnings to fund the development and growth of its business, to repay indebtedness and for general corporate purposes, and therefore, does not anticipate paying any cash dividends on its Common Stock in the foreseeable future.
The price of our Common Stock may fluctuate significantly, which could negatively affect us and 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 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.
ITEM 1B. UNRESOLVED STAFF COMMENTS.
None.
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.
In the ordinary course of business, the Company may be involved in litigation and claims arising from operations. As of December 31, 2021, and through the filing date of this Annual Report on Form 10-K, management does not believe the ultimate resolution of any such actions or potential actions of which management is currently aware will have a material effect on the consolidated financial position or results of operations.
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
The Company's Common Stock is traded on the NYSE American under the symbol "EP".
Stockholders
At both December 31, 2021, and March 31, 2022, there were approximately 900 stockholders of record of the Company's Common Stock.
Dividends
The Company has never paid cash dividends on its Common Stock. The Company intends to retain future earnings for use in its business and, therefore, does not anticipate paying cash dividends on its Common Stock in the foreseeable future. Future payment of dividends will depend upon, but not be limited to, the Company’s 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 the Company for the year ended December 31, 2021.
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 |
| ITEM 7. | MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS. |
The following discussion should be read together 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
The Company's primary business is the exploration and development of oil and gas interests. The Company has incurred significant losses from operations, and there is no assurance that it will achieve profitability or obtain funds necessary to finance its future operations.
The Company seeks to increase shareholder value by growing reserves, production, revenues, and cash flow from operating activities by executing its mission to use highly-skilled personnel to thoughtfully and expertly spend capital to realize reserves on producing properties.
Management places emphasis on operating cash flow in managing its business, as operating cash flow considers the cash expenses incurred during the period and excludes non-cash expenditures not related directly to the Company’s operations.
Business Strategy
The Company’s business strategy is to obtain long-term growth in reserves and cash flow on a cost-effective basis utilizing experienced personnel throughout the Company. Management regularly evaluates potential acquisitions of properties that would enhance current core areas of operation.
2021 XTO Acquisition
On March 12, 2021 the Company, through its wholly owned subsidiary Empire New Mexico, entered into a purchase and sale agreement with XTO Holdings, LLC (a subsidiary of ExxonMobil) (the “Seller’) to acquire, among other things, certain oil and natural gas properties in New Mexico. The purchase price was $17,800,000 subject to customary adjustments. The transaction closed on May 14, 2021 with an effective date of January 1, 2021. For more information about the transaction, refer to the financial statements and footnotes incorporated by reference herein.
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Results of Operations
The following table reflects our summary 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.
| Years Ended December 31, | ||||||||||||||||
| 2021 | 2020 | Variance | Variance % | |||||||||||||
| Oil revenues | $ | 22,326,289 | $ | 5,452,187 | 16,874,102 | 309 | % | |||||||||
| Natural gas revenues | 2,593,081 | 347,355 | 2,245,726 | 647 | % | |||||||||||
| NGL revenues | 3,396,097 | 100,718 | 3,295,379 | 3272 | % | |||||||||||
| Total revenues from product sales | 28,315,467 | 5,900,260 | ||||||||||||||
| Lease operating expense | 14,095,708 | 4,871,755 | 9,223,953 | 189 | % | |||||||||||
| Production and ad valorem taxes | 2,102,772 | 346,101 | 1,756,671 | 508 | % | |||||||||||
| Depreciation, depletion, amortization and accretion | 3,716,754 | 4,047,877 | (331,123 | ) | -8 | % | ||||||||||
| Impairment expense | — | 8,671,303 | (8,671,303 | ) | -100 | % | ||||||||||
| General and administrative expense (excluding stock-based compensation) | 7,366,061 | 5,424,304 | 1,941,757 | 36 | % | |||||||||||
| Stock-based compensation | 1,095,970 | 1,949,500 | (853,530 | ) | -44 | % | ||||||||||
| Cash-based interest expense | 436,053 | 521,187 | (85,134 | ) | -16 | % | ||||||||||
| Non-cash interest expense | 8,164,646 | — | 8,164,646 | 100 | % | |||||||||||
| Operating Loss | (473,370 | ) | (17,583,006 | ) | 17,109,636 | -97 | % | |||||||||
| Net Loss | (18,614,962 | ) | (16,835,433 | ) | 1,779,529 | 11 | % | |||||||||
Revenues
Revenues increased as a result of more volumes produced from legacy assets due to successful execution of the Company’s mission to cost-effectively produce more volumes paired with the XTO acquisition’s revenues and volumes brought online from efforts to make the field produce more volumes combined with favorable pricing environments in the Company’s core operating areas. Approximately $11.2 million in oil revenues, $1.7 million in gas revenue, and $3.1 million in NGL revenue was attributed to production acquired with the XTO acquisition.
Lease Operating Expense and Taxes
Lease operating expense rose with the XTO acquisition and in response to the Company’s execution of its mission to increase production in its legacy assets. The Company has worked to cost-effectively increase production throughout its asset base utilizing experienced personnel and third-party service providers. Production and ad valorem taxes have increased as a direct result of the XTO acquisition’s properties and increased volumes produced and sold. The acquisition of New Mexico assets accounted for approximately $5.0 million of the increase in lease operating expenses and $1.3 million of the increase in production and ad valorem taxes.
Depreciation, Depletion, Amortization and Accretion and Impairment
There were no indicators of impairment on the Company’s properties at year-end, primarily due to favorable futures pricing at December 31, 2021. Due to favorable pricing realized throughout 2021 and the addition of PDP reserves in New Mexico, DDA expense decline year-over-year from approximately 13% in 2020 to 6% in 2021.
General and Administrative Expense
The Company’s implemented a new Board of Directors compensation plan in 2021 resulting in board compensation paid of approximately $475,000 in 2021, exclusive of stock-based compensation received. Fees paid for legal and outsourced services increased by approximately $425,000 as a direct result of acquisition-related work, SEC filings related to the Company’s operations, and the Company’s successful uplisting from the OTCQB to be freely traded on the NYSE American. Outsourced accounting fees increased by approximately $375,000 as additional work was required to integrate the New Mexico assets into the existing accounting system as well as additional resources required to perform routine accounting services on the new assets. Also included in general and administrative expenses is $989,000 in non-cash right to buy costs related to the unsecured notes payable discussed in the Related Party Transactions note below.
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The Company utilizes stock-based compensation to compensate members of management and retain talented personnel. The Company anticipates stock-based compensation to continue to be utilized in 2022 and beyond to attract and retain talented personnel.
Interest Expense
Cash-based interest expense declined with a corresponding decrease in the Company’s Credit Facility. The Company has minimal interest-bearing vehicle and equipment notes payable.
Non-cash interest expense is fully attributable to the related party notes payable as described in Related Party Transactions below.
Liquidity
As of December 31, 2021, the Company had approximately $3.6 million cash on hand and approximately $300,000 available on its Credit Facility. The Company expects to incur costs related to future oil and natural gas acquisitions for the foreseeable future. It is expected that management will use a combination of cash flows from operations as well as seeking additional debt and equity funding for these acquisitions and to fund ongoing operations.
Working Capital
Working capital (presented below) was $1.1 million as of December 31, 2021 compared to a deficit of $3.9 million as of December 31, 2020, representing a change of approximately $5 million. This change is primarily a result of the acquisition of producing properties in New Mexico, which served to increase volumes sold for the year ended December 31, 2021, as well as the stronger pricing environment in 2021.
| December 31, | ||||||||
| 2021 | 2020 | |||||||
| Current Assets | 13,118,020 | 2,222,533 | ||||||
| Current Liabilities | 12,054,487 | 6,072,710 | ||||||
| Working Capital (Deficit) | 1,063,533 | (3,850,177 | ) | |||||
Cash Flows
| Year Ended December 31, | ||||||||||||
| Cash flows provided by (used in): | 2021 | 2020 | Variance | |||||||||
| Operating activities | $ | 3,170,282 | $ | (1,723,257 | ) | $ | 4,893,539 | |||||
| Investing activities | (24,716,878 | ) | 856,290 | (25,573,168 | ) | |||||||
| Financing activities | 25,000,772 | 1,024,662 | 23,976,110 | |||||||||
Cash Flows from Operating Activities
The Company incurred approximately $18.0 million in non-cash expenses related to the convertible notes payable (See Related Party Transactions for more information) that contributed to a net loss for financial reporting purposes. Ongoing operations from core assets contributed to cash flows provided by operating activities for the year ended December 31, 2021.
Cash Flows from Investing Activities
Cash flows from investing activities primarily increased due to the XTO acquisition that occurred in May 2021 and established the Company in the state of New Mexico, the Company’s largest single acquisition to date that resulted in cash outflows of approximately $17.9 million. The Company also participated in the drilling of four non-operated wells through its Empire North Dakota subsidiary that had a cash outflow of approximately $2.5 million for the year ended December 31, 2021. As part of the XTO acquisition, the Company entered into an agreement to create a sinking fund for future plugging liabilities, paying approximately $4.8 million into that fund for the year.
Cash Flows from Financing Activities
The XTO acquisition and operations executing the Company’s mission were funded by proceeds from debt issued of approximately $20.5 million as well as proceeds from stock and warrant issuances of approximately $11.3 million. The Company has quarterly payment obligations related to its bank debt of $300,000 per quarter in addition to minimal monthly payments for notes payable arising from the purchase of vehicles and equipment.
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Related Party Transactions
The issuance of the Secured Note and an Unsecured Note to Energy Evolution as described below are related party transactions for accounting purposes, but are not required to be disclosed under Item 13 of this Form 10-K.
Senior Secured Convertible Note
On May 14, 2021, Empire New Mexico entered into a Senior Secured Convertible Note Agreement (the “Secured Note”) in the amount of $16,250,000 with Energy Evolution Master Fund, Ltd., a related party (“Energy Evolution”). The Secured Note was collateralized by all assets of Empire New Mexico prior to its conversion to common stock in December 2021. Due to the terms of the Secured Note, the transaction had the following non-cash elements for the year ended December 31, 2021:
| - | A debt discount of $2.2 million |
| - | $2.2 million in derivative liability considerations, including the valuation of the redemption option |
| - | Non-cash interest expense of $7.4 million |
On September 29, 2021 the parties entered into a Loan Modification Agreement pursuant to which Energy Evolution exchanged $6,500,000 in principal under the Secured Note in exchange for 1,326,302 shares of common stock, warrants to purchase 500,000 shares of the Company’s common stock at $5 per share and amended certain terms of the remaining $5,700,000 of principal under the Secured Note.
On December 30, 2021, the Secured Note was amended to allow full conversion of the remaining balance and Energy Evolution converted 100% of the remaining principal ($5.7 million) and accrued interest ($55,000) outstanding at that date into 1,154,085 shares of the Company’s common stock.
Unsecured Convertible Notes
In May 2021 the Empire New Mexico entered into $3,243,000 of Unsecured Convertible Notes (the “Unsecured Notes”) with a group of accredited investors, including the Company’s related party Energy Evolution, constituting $1,500,000 of the total Unsecured Convertible Notes. The Unsecured Notes had a maturity of May 9, 2022 with a single payment and interest at 5%. The Unsecured Note holders had the ability to convert their notes to common stock of the Company at the lesser of $5 per share or the price per share offered by the Company if the Company has a future capital raise for an aggregate 648,600 shares of common stock (without giving effect to any interest that may be converted). At December 31, 2021 $2,918,000 of the Unsecured Notes had been converted into 583,600 shares of common stock of the Company and 5,594 shares of common stock have been issued as payment for accrued interest on the Unsecured Note. The remaining Unsecured Notes in the amount of $325,000 were repaid in September 2021. Amortization of these notes was recorded as a non-cash interest expense of approximately $545,000.
The Company determined the embedded conversion features of the Unsecured Notes were equity-classified financing instruments. The fair value of the conversion feature was determined using a beneficial conversion model based on a 60-day weighted average stock price and the maximum number of shares to be received if converted. As issuance, the amount recorded to additional paid in capital was $544,824. The discount associated with these transactions is amortized under the interest method and resulted in interest expense of $544,824 for the year ended December 31, 2021.
As an inducement for investors to enter into the Unsecured Convertible Notes, the Company’s Chief Executive Officer and President collectively offered to each investor the right to purchase a number of shares of common stock equal to 40% of such investor’s principal balance under its Unsecured Convertible Note at $3 per share (the “right to buy”). Energy Evolution exercised its right to buy 150,000 shares of the Company’s common stock. In conjunction with the conversion of the Unsecured Notes, each of the Company’s Chief Executive Officer and President partially exercised a warrant and options to purchase 160,900 shares at an exercise price of $1.00 and $1.32 respectively. The Company determined that offering the “right to buy” shares resulted in a non-cash expense of $989,155 of the Company based on the fair value of contributions made by the Company’s Chief Executive Officer and President on its behalf. The fair value of the “right to buy” shares was determined using a Black-Scholes model. The expense is included in General and Administrative in the Consolidated Statement of Operations.
Effective Tax Rate
For all periods presented, the Company's effective tax rate is 0%. The Company has generated net operating losses since inception, which would normally reflect a tax benefit in the statement of operations and a deferred asset on the balance sheet. However, because of the current uncertainty as to the Company's ability to achieve profitability, a valuation reserve has been established that offsets the amount of any tax benefit available for each period presented in the statements of operations.
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OFF-BALANCE SHEET ARRANGEMENTS
The Company does not have any off-balance sheet arrangements.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
The preparation of financial statements in conformity with generally accepted accounting principles in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Because estimates and assumptions require significant judgment, future actual results could differ from those estimates and could have a significant impact on the Company's results of operations, financial position and cash flows. The Company re-evaluates its estimates and assumptions at least on a quarterly basis. The following policies may involve a higher degree of estimation and assumption:
Oil and Natural Gas Properties
The Company uses 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. Exploration costs, including unsuccessful exploratory wells, geological and geophysical are charged to operations as incurred. Depreciation, depletion and amortization of the leasehold and development costs that are capitalized for proved oil and natural gas properties are computed using the units-of-production method, at the field level, based on total proved reserves and proved developed reserves, respectively, as estimated by independent petroleum engineers. Oil and natural gas properties are periodically assessed for impairment whenever changes in facts and circumstances indicate a possible significant deterioration in the future cashflows expected to be generated by an asset group, but at least annually. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets, generally on a state-by-state basis. All of our properties are located within the continental United States.
All costs related to unsuccessful exploratory wells are expensed when such wells are determined to be non-productive and other exploration costs, including geological and geophysical costs, are expensed as incurred. The application of the successful efforts method of accounting requires management's judgment to determine the proper designation of wells as either developmental or exploratory, which will ultimately determine the proper accounting treatment of the costs incurred. The results from a drilling operation can take considerable time to analyze, and the determination that commercial reserves have been discovered requires both judgment and application of industry experience. Wells may be completed that are assumed to be productive and actually deliver oil and gas in quantities insufficient to be economic, which may result in the abandonment of the wells at a later date. The evaluation of oil and gas leasehold acquisition costs requires management's judgment to estimate the fair value of exploratory costs related to drilling activity in a given area.
Impairment of Oil and Gas Properties
Management’s assessment of the results of 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 economic to develop some of these unproved properties.
Oil and Natural Gas Reserve Quantities
Reserve quantities and the related estimates of future net cash flows affect periodic calculations of depletion, impairment of oil and natural gas properties, and asset retirement obligations. 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 Financial Accounting Standards Board (“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, Cawley Gillespie Associates. The independent petroleum engineers evaluated 100% of the Company’s estimated proved producing reserve quantities and their related future net cash flows as of December 31, 2021. 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. Management makes changes to depletion rates, impairment calculations, and asset retirement obligations in the same period that changes to reserve estimates are made.
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Depreciation, Depletion and Amortization
The rate used to calculate and record DDA is dependent upon estimates of total proved developed reserves, which incorporate various assumptions and future projections. If the estimates of total proved or proved developed reserves decline, DDA expense increases. Such a decline in reserves may result from lower commodity prices, which may make it uneconomic to operate wells due to higher cost fields. Management is unable to predict changes in reserve quantity estimates as such quantities are dependent on the success of executing the Company’s mission as well as future economic conditions.
Asset Retirement Obligation
Asset retirement obligations (“AROs”) 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. Increases in the ARO liability due to passage of time impact net income as accretion expense. The related capitalized cost, including revisions thereto, is charged to expense through DDA over the life of the field.
Stock-Based Compensation
The Company recognized stock-based compensation expense associated with restricted stock units, which consists of time-based awards. The Company 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 Company’s common stock, $0.001 par value per share on the grant date. The Company classifies grants to be settled in shares as equity awards.
Income Taxes and Uncertain Tax Positions
The Company’s 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. The effective tax rate for financial statement purposes is 0% for all periods presented.
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, 2021 and 2020, a 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. The Company has no uncertain tax positions at either December 31, 2021 or December 31, 2020.
Revenue Recognition
The Company predominantly derives its revenue from the sale of produced oil, natural gas and NGLs. Revenues are recognized when the recognition criteria of FASB ASC Topic 606, Revenue from Contracts with Customers, are met, which generally occurs at the point in which title passes to the customers. We receive payment from one to three months after delivery. At the end of each quarter, we estimate the amount of production delivered to purchasers and the price we will receive. Variances between our estimated revenue and actual payment are recorded in the month the payment is received. Historically, differences have been insignificant.
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| ITEM 7A. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK. |
The Company is a smaller reporting company as defined by Rule 12b-2 of the Exchange Act and is 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. |
The Company’s 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 Chief Executive Officer and Chief 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.
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 Chief Executive Officer and Chief 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 was not effective as of December 31, 2021 due to a material weakness.
A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting such that there is a possibility that a material misstatement in our interim financial statements will not be prevented or detected on a timely basis. A material weakness in internal control application was discovered related to the internal controls over financial reporting, including disclosures around complex and non-routine transactions. Management believes the Company’s lack of sufficient accounting personnel with appropriate accounting expertise to appropriately apply GAAP for complex and non-routine transactions and prepare associated financial statement disclosures amounts to a material weakness in its internal control over financial reporting.
As a result, at December 31, 2021 and on the date of this Report, its internal control over financial reporting is not effective.
Management’s Plant to Remediate the Material Weakness
Management has evaluated the material weakness described above and is in the process of updating its design and implementation of internal control over financial reporting to remediate the aforementioned material weakness and enhance the Company’s internal control environment, including the hiring of our Chief Accounting Officer in October 2021 and will continue to increase our accounting and financial reporting capacity to effectively gather, analyze and review information related to financial reporting in a timely manner. However, the implemented and enhanced controls have not operated for a sufficient period of time to demonstrate that the material weakness was remediated as of, or subsequent to, December 31, 2021. We are committed to continuing to improve our internal control processes and will continue to diligently and vigorously review our financial reporting controls and procedures.
Changes in Internal Controls over Financial Reporting
While we continue to implement design enhancements to our internal control procedures, we believe that, other than the changes described above regarding the ongoing remediation efforts, 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 2021 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 Annual 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.
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| ITEM 9B. | OTHER INFORMATION. |
None.
| ITEM 9C. | DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS. |
Not applicable.
PART III
| ITEM 10. | DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE. |
The following lists the directors and executive officers of the Company:
| Name | Age | Position |
| Thomas W. Pritchard | 60 | Chief Executive Officer and Director |
| Michael R. Morrisett | 58 | President and Director |
| Eugene J. Sweeney | 54 | Chief Operating Officer |
| Anthony N. Kamin | 61 | Director and Co-Chairman of the Board |
| Phil E. Mulacek | 61 | Director and Co-Chairman of the Board |
| Benjamin J. Marchive II | 42 | Director |
| Mason H. Matschke | 59 | Director |
Directors hold office until their successors are elected by the stockholders of the Company and qualified. Executive officers serve at the pleasure of the Board of Directors.
Recommendation of Nominees to the Company's Board of Directors
The Company’s Board of Directors does not have a nominating committee. On November 19, 2021, the Company’s Board adopted resolutions requiring the independent directors of the Board (the “Independent Directors”) to participate in the consideration of director nominees and recommend for the Board’s selection the director nominees. The Independent Directors will consider director candidates submitted to them by other directors, employees and stockholders. The Independent Directors may engage professional search firms to assist them in identifying and evaluating potential candidates. Any stockholder recommendations of candidates proposed for consideration by the Independent Directors should include the candidate’s name and qualifications for director, reasons for the recommendation and the candidate’s written consent to being considered as a director nominee and should be addressed to: Attention: Independent Directors, c/o Secretary, 2200 S. Utica Place, Suite 150, Tulsa, Oklahoma 74114. The Independent Directors may require the stockholder submitting the recommendation or the recommended candidate to furnish such other information as the Independent Directors may reasonably request. In addition, the Company’s Amended and Restated Bylaws provide a process for stockholders to nominate directors for consideration at a meeting of stockholders. In considering prospective nominees for the Board, the Independent Directors will
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endeavor to find individuals of high integrity who have a solid record of accomplishment in their chosen fields and who possess the qualifications, qualities and skills to effectively represent the best interests of all stockholders. Candidates are selected for their ability to exercise good judgment and provide practical insights and diverse perspectives. The Independent Directors consider the following qualifications at a minimum to be required in recommending to the Board potential new Board members or the continued service of existing members:
| · | an attained position of leadership in the candidate’s field of endeavor; |
| · | business and/or financial expertise; |
| · | integrity; |
| · | objectivity; |
| · | demonstrated exercise of sound business judgment; |
| · | expertise relevant to Empire Petroleum’s lines of business; |
| · | corporate governance experience; |
| · | ability to serve the interests of all stockholders; |
| · | ability to devote the time, energy and attention as may be necessary to properly discharge his or her responsibilities as a director; and |
| · | independence; at least 50% of the Board shall consist of independent directors, as defined in the rules of the NYSE American. |
Other than the foregoing, there are no stated minimum criteria for director nominees, although the Independent Directors may also consider such other factors as they may deem are in the best interests of the Company and its stockholders. When considering potential nominees for the Board, the Independent Directors will consider the criteria above and each potential nominee’s individual skills and qualifications in context of the current composition of the Board and needs of the Board at such time. In connection therewith, the Independent Directors will consider diversity in professional background, experience, expertise, perspective, age, gender and ethnicity with respect to Board composition as a whole, although the Board does not have a specific diversity policy. With respect to diversity, particular emphasis is placed on identifying candidates whose skills and characteristics complement and augment the make-up of the Board as a whole and the needs of the Board given the circumstances of the Company. If the Company is legally required by contract or otherwise to provide third parties with the ability to nominate and/or appoint directors (e.g., the Company’s Series A Voting Preferred Stock), the selection and nomination of such directors is not subject to the foregoing process.
Identification of Audit Committee; Audit Committee Financial Expert
The Company has a separately-designated standing audit committee established in accordance with section 3(a)(58)(A) of the Exchange Act. The audit committee’s members are Anthony Kamin and Mason Matschke, both of whom are independent under the current director independence standards of the NYSE American. The Board has determined the Company does not have an audit committee financial expert serving on its audit committee. The Board has determined that both Messrs. Kamin and Matschke are able to read and understand fundamental financial statements and are financially sophisticated as contemplated under the rules of the NYSE American. The Board does not have an audit committee financial expert because it has not recruited one but will periodically review the need to add an expert.
Code of Ethics
The Company has adopted a Code of Business Conduct and Ethics that applies to all of the Company's directors and employees, including the Company's principal executive officer, principal financial officer and principal accounting officer or persons performing similar functions. The Code of Business Conduct and Ethics is available on the Company’s website at https://empirepetroleumcorp.com under the “Investor Relations – Corporate Governance” caption. If the Company amends or waives a provision of the Code of Business Conduct and Ethics that applies to the principal executive officer, principal financial officer, principal accounting officer or persons performing similar functions, the Company will post the amendment or waiver at the same location on the Company’s website.
Delinquent Section 16(a) Reports
Section 16(a) of the Securities Exchange Act of 1934, as amended, requires the Company's directors, officers, and persons who beneficially own more than 10 percent of a registered class of the Company's equity securities, to file with the SEC initial reports of ownership and reports of changes in ownership of Common Stock and other equity securities of the Company.
Based solely on a review of the reports filed with the SEC and any written representations that no other reports were required during the year ended December 31, 2021, to the Company's knowledge, all Section 16(a) filing requirements applicable to its officers, directors and greater than 10% beneficial owners during the year ended December 31, 2021 were complied with on a timely basis, except that the initial report for (a) each of Messrs. Marchive and Matschke and Energy Evolution Master Fund, Ltd. was filed late and (b) Mr. Pritchard inadvertently omitted a holding which was later reported on a year-end report on Form 5.
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| ITEM 11. | EXECUTIVE COMPENSATION. |
Executive Compensation
The following table set forth certain information regarding compensation of the Company's named executive officers. The persons named below constitute all of the executive officers of the Company as of December 31, 2021. On August 18, 2021, each of Messrs. Pritchard and Morrisett entered into an Employment Agreement with the Company. For additional information regarding their employment agreements, see “Employment Agreements” below.
| Name and Principal Position | Year | Salary ($) | Bonus ($) | Stock Awards | Option Awards1 ($) | Non-Equity Incentive Plan Compensation ($) | Life Insurance Premiums Paid ($) | All Other Compensation ($) | Total ($) | |||||||||||||||||||||||||
| Thomas W. Pritchard | 2021 | 250,000 | 125,000 | — | — | — | 8,989 | 10,302 | (3) | 394,291 | ||||||||||||||||||||||||
| Chief Executive Officer | 2020 | 226,667 | 287,750 | — | 779,800 | — | — | 174,900 | (2) | 1,469,117 | ||||||||||||||||||||||||
| Michael R. Morrisett | 2021 | 250,000 | 125,000 | — | — | — | 8,902 | 20,987 | (3) | 404,889 | ||||||||||||||||||||||||
| President | 2020 | 226,667 | 287,750 | — | 779,800 | — | — | 174,900 | (2) | 1,469,117 | ||||||||||||||||||||||||
_______________________
1 For further information on the assumptions used in the valuation of these awards, see Note 11 included in the Notes to Consolidated Financial Statements included in this Annual Report on Form 10-K. The amounts shown do not represent the amounts paid to the executives.
2 On December 31, 2020, warrant certificates issued to Messrs. Pritchard and Morrisett pursuant to which each such named executive officer had the right to acquire 125,000 shares of the Company’s common stock at an exercise price of $1.00 per share were extended so that such warrant certificates can be exercised on or before April 2, 2029 to make such grants consistent with the 2019 Stock Plan. On December 31, 2020, each of Messrs. Pritchard and Morrisett were issued options to acquire 500,000 shares of the Company’s common stock at an exercise price of $1.40 per share under the 2019 Stock Plan.
3 All Other Compensation in 2021 consists of vehicle allowances and club dues.
Director Compensation
Annual compensation for non-employee board members, as established in August 2021, is as follows:
| · | Non-chair, non-employee board members - $80,000 per year, with pro-rata adjustments based on date of service as necessary |
| · | Chair, non-employee board members – additional $9,000 per quarter with pro-rata adjustments based on date of service as necessary |
| · | 30,000 shares of the Company’s common stock granted at December 31, 2021 with pro-rata adjustments based on date of service |
| · | The Company reimburses directors for out-of-pocket expenses in connection with attending Board and committee meetings |
| · | The Company does not pay its employees who serve on the Board of Directors any additional compensation for Board membership |
The following table shows total compensation received in 2021 by each of the Company’s non-employee directors.
| Name | Fees Earned or Paid in Cash ($) |
Stock Awards1 ($) |
Total ($) | |||
| Anthony N. Kamin | 116,000 | — | 116,000 | |||
| Phil E. Mulacek | 23,200 | — | 23,200 | |||
| Benjamin J. Marchive II | 16,000 | — | 16,000 | |||
| Mason H. Matchske | 53,333 | — | 53,333 |
1 As of December 31, 2021, Mr. Kamin had outstanding options to acquire 75,000 shares related to a 2020 grant date.
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Outstanding Equity Awards at December 31, 2021
The following table sets forth certain information regarding outstanding equity awards of the Company's named executive officers.
| Option Awards | ||||||||||
| Name | Number of securities underlying unexercised options (#) exercisable | Number of securities underlying unexercised options (#) unexercisable | Equity incentive plan awards: Number of securities underlying unexercised unearned options (#) | Option Exercise Price ($) | Option Expiration Date | |||||
| Thomas Pritchard | 589,100 | — | — | 1.32 | 4/2/2029 | |||||
| 500,000 | — | — | 1.40 | 12/31/2030 | ||||||
| Michael Morrisett | 589,100 | — | — | 1.32 | 4/2/2029 | |||||
| 500,000 | — | — | 1.40 | 12/31/2030 | ||||||
Employment Agreements
On August 18, 2021 (the “Effective Date”), the Company entered into an Employment Agreement with Thomas W. Pritchard, Chief Executive Officer of the Company.
The initial term of Mr. Pritchard’s Employment Agreement is three years; provided, however, that commencing on the third anniversary of the Effective Date of the Employment Agreement and each subsequent annual anniversary date, the term shall be automatically extended so as to terminate one year from such anniversary date, unless written notice of non-renewal is delivered by the Company or Mr. Pritchard within certain time periods.
Mr. Pritchard’s initial guaranteed minimum base salary is $250,000 per year (“Guaranteed Base Salary”), but to the extent that funds are available and subject to the discretion of the Board of Directors of the Company (the “Board”), the Company may pay Mr. Pritchard additional salary compensation up to the maximum amount of $35,000 per year. Mr. Pritchard is eligible to receive a target annual bonus of 100% of his Actual Base Salary (as defined in the Employment Agreement) for each calendar year during the term of the Employment Agreement, with the actual amount of such bonus determined at the discretion of the Board based on performance targets established by the Board. Mr. Pritchard is eligible to participate in the Company’s long-term equity incentive program adopted by the Board; provided that he is entitled to an annual award of 25,000 shares of common stock of the Company.
If Mr. Pritchard’s employment with the Company terminates for any reason, including Disability (as defined in the Employment Agreement) or death, Mr. Pritchard will be entitled to a lump sum cash payment consisting of his pro rata Actual Base Salary as earned and unpaid, and unreimbursed expenses, through the date of termination (collectively, the “Accrued Amounts”). In each case, any unvested equity awards held by Mr. Pritchard will vest and payout only in accordance with the applicable award agreements for such equity awards.
If Mr. Pritchard’s employment is terminated by the Company for convenience or Mr. Pritchard resigns for Good Reason (as defined in the Employment Agreement), then, in addition to the Accrued Amounts, Mr. Pritchard will be entitled to the following:
• monthly payments of his Guaranteed Base Salary for the Severance Period; and
• monthly payments equivalent to the cost of COBRA for a certain period of time.
Severance Period is defined in Mr. Pritchard’s Employment Agreement as 12 months if his employment is terminated on or before the first anniversary of the Effective Date and such period is increased by three months for each consecutive year that he remains employed by the Company; provided that the Severance Period can never be greater than 24 months. Payment of such amounts are conditioned on Mr. Pritchard’s execution and delivery to the Company of a waiver and release and his compliance with the covenants regarding confidentiality, non-competition, non-solicitation and intellectual property set forth in the Employment Agreement.
On August 18, 2021, the Company also entered into an Employment Agreement with Michael R. Morrisett, President of the Company. The terms and conditions of Mr. Morrissett’s Employment Agreement are identical in all material respects to Mr. Pritchard’s Employment Agreement.
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| ITEM 12. | SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS. |
Securities Authorized for Issuance under Equity Compensation Plans
On April 3, 2019, the Board of Directors of the Company adopted the Empire Petroleum Corporation 2019 Stock Option Plan (the "Stock Option Plan"). The total number of shares of common stock that may be issued pursuant to stock options under the Stock Option Plan is 2,500,000. Further, on April 3, 2019 the Company granted Mr. Pritchard and Mr. Morrissett each, options to purchase 625,000 shares of common stock of the Company at an exercise price of $1.32 per share. On December 31, 2020, the Company granted certain members of management and a member of the Board of Directors options to purchase 1,250,000 shares of common stock of the Company at an exercise price of $1.40 per share. No further grants will be made under the Stock Option Plan.
On August 27, 2021, the Board of Directors of the Company adopted the Empire Petroleum Corporation 2021 Stock and Incentive Compensation Plan (the “Incentive Plan”). The total number of shares of common stock that may be issued pursuant to the Incentive Plan is 750,000. As of December 31, 2021, grants were made amounting to 187,500 options.
| (a) | (b) | (c) | |
| Number of securities | |||
| remaining available | |||
| for future | |||
| Number of securities | issuance under | ||
| to be issued upon | Weighted-average | equity compensation | |
| exercise of | exercise price of | plans (excluding | |
| outstanding options | outstanding options | securities reflected | |
| Plan Category | and rights | and rights | in column (a) |
| 2019 Plan: | |||
| Equity compensation plans | |||
| not approved by security holders | |||
| 2,500,000 | $1.36 | — | |
| 2021 Plan: | |||
| Equity compensation plans | |||
| approved by security holders | 187,500 | $12.20 | 562,500 |
| Total | 2,687,500 | 562,500 |
Security Ownership of Certain Beneficial Owners and Management
The following table sets forth information regarding the beneficial ownership of our Common Stock as of March 15, 2022 for:
* Each person who is known to own beneficially more than 5% of our outstanding Common Stock;
* Each of our executive officers and directors; and
* All executive officers and directors as a group.
The percentage of beneficial ownership for the following table is based on 19,855,107 shares of Common Stock outstanding as of March 15, 2022.
Unless otherwise indicated below, to the Company's knowledge, all persons and entities listed below have sole voting and investment power over their shares of Common Stock.
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Security Ownership of Certain Beneficial Owners
| Name and address of beneficial owner | Amount and nature of beneficial ownership | Percent of class (1) | ||
| Puckett Land Company | 1,000,000 | 5% | ||
| 5460 S. Quebec St., Suite 250 | ||||
| Greenwood Village, CO 80111 | ||||
| Energy Evolution Master Fund, LTD | 5,466,637 | (2) | 26.86% | |
| 25025 I-45 North, Suite 420 | ||||
| The Woodlands, Texas 77380 | ||||
| Total | 6,466,637 | 31.77% |
_______________________
(1) The percentage ownership for each person or entity is calculated in accordance with the rules of the SEC, which provide that any shares a person or entity is deemed to beneficially own by virtue of having a right to acquire shares upon the conversion of options or other rights are considered outstanding solely for purposes of calculating such person's percentage ownership.
(2) Includes 500,000 of common stock shares issued upon exercise of $5.00 warrants.
Security Ownership of Management
| Name and address of beneficial owner | Amount and nature of beneficial ownership | Percent of class (1) | ||
| Michael R. Morrisett | 1,512,382 | (2) | 7.22% | |
| President and Director | ||||
| 2200 South Utica Place, Suite 150 | ||||
| Tulsa, Oklahoma 74114 | ||||
| Thomas W. Pritchard | 1,108,683 | (3) | 5.29% | |
| Chief Executive Officer and Director | ||||
| 2200 South Utica Place, Suite 150 | ||||
| Tulsa, Oklahoma 74114 | ||||
| Anthony Kamin | 1,374,528 | (4) | 6.64% | |
| Director and Board Co-Chairman | ||||
| 2200 South Utica Place, Suite 150 | ||||
| Tulsa, Oklahoma 74114 | ||||
| Phil Mulacek | 3,424,021 | (5) | 17.13% | |
| Director and Board Co-Chairman | ||||
| 25025 I-45 North, Suite 420 | ||||
| The Woodlands, Texas 77380 | ||||
| Eugene J. Sweeney | 92,500 | (6) | 0.47% | |
| Chief Operating Officer | ||||
| 2200 South Utica Place, Suite 150 | ||||
| Tulsa, Oklahoma 74114 | ||||
| Mason H. Matschke | 660,277 | (7) | 3.32% | |
| Director | ||||
| 2200 South Utica Place, Suite 150 | ||||
| Tulsa, Oklahoma 74114 | ||||
| Benjamin J. Marchive II | — | 0% | ||
| Director | ||||
| 2200 South Utica Place, Suite 150 | ||||
| Tulsa, Oklahoma 74114 | ||||
| Total | 8,172,391 | 40.07% |
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(1) The percentage ownership for each person is calculated in accordance with the rules of the SEC, which provide that any shares a person is deemed to beneficially own by virtue of having a right to acquire shares upon the conversion of options or other rights are considered outstanding solely for purposes of calculating such person's percentage ownership.
(2) The total includes options to purchase 1,089,100 shares of common stock at an exercise price of $1.32 and $1.40 per share.
(3) The total includes options to purchase 1,089,100 shares of common stock at an exercise price of $1.32 and $1.40 per share, and 19,583 shares owned by Pritchard Energy Partners.
(4) The total includes options to purchase 75,000 shares of common stock at an exercise price of $1.40 per share, 125,000 shares of common stock issued upon the exercise of $0.60 warrants, 625 shares of common stock issued upon the exercise of $1.00 warrants, and 625,000 shares of common stock issued upon the exercise of $2.00 warrants.
(5) The total includes 137,000 common stock shares issued upon the exercise of $2.00 warrants.
(6) The total includes options to purchase 62,500 shares of common stock at an exercise price of $12.20 per share and 15,000 shares issued upon the exercise of $2.00 warrants.
(7) The total includes 16,875 common shares issued upon the conversion of $2.00 warrants.
| ITEM 13. | CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE. |
Director Independence
The Company’s common stock is currently listed on the NYSE American. Under the corporate governance standards of the NYSE, generally, a director does not qualify as independent if the director (or in some cases, members of the director’s immediate family) has, or in the past three years has had, certain relationships or affiliations with the Company, the Company’s auditors or other companies that do business with the Company. The Company’s Board of Directors has determined that all of the Company’s directors, except Messrs. Pritchard and Morrisett, are independent under the NYSE standards. The Board determined that none of the independent directors has any material relationship with the Company that could impair such individual’s independence. Messrs. Pritchard and Morrisett are not considered to be independent directors because of their employment as executive officers of the Company. Each member of each of the Company’s Audit and Compensation Committees also qualifies as independent under NYSE standards.
Related Party Transactions
For information regarding a joint development agreement and loan agreement entered into with Petroleum Independent Exploration, LLC, an entity controlled by the Company’s Co-Chairman of the Board (Phil E. Mulacek), see Note 5 to the financial statements of the Company set forth at the end of this Form 10-K. Neither Petroleum Independent Exploration, LLC nor Phil E. Mulacek was a related party at the time the Company entered into the joint development agreement and loan agreement.
| ITEM 14. | FEES OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM. |
The following is a summary of the fees billed or to be billed to the Company by Moss Adams and HoganTaylor LLP, the Company's current and former independent registered public accounting firms, respectively, for professional services rendered for the fiscal years ended December 31, 2021 and December 31, 2020 in which each firm was the designated independent auditor:
| Fee Category | Fiscal 2021 Fees | Fiscal 2020 Fees | ||||||
| Audit Fees (1) | $ | 453,250 | $ | 265,000 | ||||
| Audit - Related Fees (2) | — | — | ||||||
| Tax Fees | — | — | ||||||
| All Other Fees (3) | — | — | ||||||
| Total Fees | $ | 453,250 | $ | 265,000 | ||||
(1) Audit Fees consist of aggregate fees billed for professional services rendered for the audit of the Company's annual financial statements and review of the interim financial statements included in quarterly reports or services that are normally provided by the independent registered public accounting firm in connection with statutory and regulatory filings or engagements for the years ended December 31, 2021 and December 31, 2020, respectively. These include work performed for the 8-K/A, S-3, and S-8 filings.
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(2) Audit-Related fees consist of aggregate fees billed for assurance and related services that are reasonably related to the performance of the audit or review of our financial statements and are not reported under "Audit Fees."
(3) All Other Fees consist of aggregate fees billed for products and services provided by independent auditors, other than those disclosed above.
Audit Committee Pre-Approval Policies and Procedures
Beginning in 2022, the Audit Committee is responsible for the appointment, compensation and oversight of the work of the independent registered public accounting firm and approves in advance any services to be performed by the independent registered public accounting firm, whether audit-related or not. The Audit Committee reviews each proposed engagement to determine whether the provision of services is compatible with maintaining the independence of the independent registered public accounting firm. As no Audit Committee was in place as of December 31, 2021, all of the fees shown above were pre-approved by the entire Board of Directors.
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.
| (2) Schedules |
NONE
| (3) Exhibits |
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| 23.1 | Consent of Moss Adams LLP (submitted herewith). |
| 23.2 | Consent of HoganTaylor LLP (submitted herewith). |
| 23.3 | Consent of Cawley, Gillespie Associates, Inc. (submitted herewith). |
| 31.1 | |
| 31.2 | |
| 32.1 | Section 1350 Certification of Thomas Pritchard, Chief Executive Officer (submitted herewith). |
| 32.2 | Section 1350 Certification of Michael R. Morrisett, principal financial officer (submitted herewith). |
| 99.1 | Cawley, Gillespie Associates, Inc. Summary Report (submitted herewith). |
| 101 | Financial Statements for XBRL format (submitted herewith). |
*Indicates a management contract or compensatory plan 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
|
|||
| Date: March 31, 2022 | By: | /s/ Michael R. Morrisett | |
| Name: Michael R. Morrisett | |||
| Title: President | |||
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 and President | March 31, 2022 | ||
| MICHAEL R. MORRISETT | (Principal Financial Officer) | |||
| /s/ Thomas Pritchard | Chief Executive Officer and Director | March 31, 2022 | ||
| THOMAS PRITCHARD | (Principal Executive Officer) | |||
/s/ Angela M. Baker |
Chief Accounting Officer |
March 31, 2022 | ||
ANGELA M. BAKER |
(Principal Accounting Officer) |
|||
|
||||
| /s/ Anthony J. Kamin | Director and Co-Chairman of the Board | March 31, 2022 | ||
| ANTHONY J. KAMIN | ||||
| /s/ Phil E. Mulacek | Director and Co-Chairman of the Board | March 31, 2022 | ||
| PHIL E. MULACEK | ||||
| /s/ Mason Matschke | Director | March 31, 2022 | ||
| MASON MATSCHKE | ||||
| /s/ Benjamin J. Marchive II | Director | March 31, 2022 | ||
| BENJAMIN J. MARCHIVE II | ||||
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED FINANCIAL STATEMENTS
CONTENTS
| Page No. | |
| Report
of Independent Registered Public Accounting Firm – Moss Adams LLP (PCAOB ID: |
40 |
| Report of Independent Registered Public Accounting Firm – HoganTaylor LLP (PCAOB ID: 483) | 43 |
| Consolidated Balance Sheets as of December 31, 2021 and 2020 | 44 |
| Consolidated Statements of Operations for the years ended December 31, 2021 and 2020 | 45 |
| Consolidated Statements of Changes in Stockholders' Equity (Deficit) for the years ended December 31, 2021 and 2020 | 46 |
| Consolidated Statements of Cash Flows for the years ended December 31, 2021 and 2020 | 47 |
| Notes to Consolidated Financial Statements | 48 |
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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Stockholders and the Board of Directors of
Empire Petroleum Corporation
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheet of Empire Petroleum Corporation and subsidiaries (the “Company”) as of December 31, 2021, the related consolidated statements of operations, stockholders’ equity and cash flows for the year then ended, and the related notes to the consolidated financial statements (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2021, and the consolidated results of its operations and its cash flows for the year then ended, 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 audit. 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 audit 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 consolidated 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 audit 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 audit included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures to respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audit provides a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below 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. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
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Evaluation of Related Party Convertible Debt and the Valuation of the Embedded Conversion Option Thereof
As described in Note 9 to the consolidated financial statements, on May 14, 2021 the Company’s wholly owned subsidiary Empire New Mexico entered into a Senior Secured Convertible Note Agreement (the “Secured Note’”) with Energy Evolution Master Fund, Ltd. (“Energy Evolution”), a related party, pursuant to which a portion of the Secured Note was convertible into common shares of the Company at the election of Energy Evolution. The value of the embedded conversion option of the Secured Note was bifurcated and accounted for separately as a derivative financial instrument; the derivative was initially recorded at fair value at the inception date and was revalued at each subsequent quarter-end date. On September 29, 2021 the parties entered into a Loan Modification Agreement (the “Amended Secured Note”) pursuant to which the Company induced the conversion of principal by Energy Evolution into common stock by increasing the maximum principal amount then convertible by Energy Evolution, issued Energy Evolution warrants to purchase additional shares of common stock at $1.25 per share and established that interest payments were to be paid in-kind or in cash at Energy Evolution’s election. Upon conversion of the amended maximum principal convertible, the remaining principal outstanding under the Secured Note became convertible into shares of common stock, the maturity date of the Secured Note was extended and the parties amended certain other terms of the Secured Note. The previously existing bifurcated derivative liability was extinguished in connection with this Amended Secured Note as Energy Evolution had fully converted the maximum amount and the Company bifurcated and recorded the newly established embedded conversion option of the remaining principal under the Amended Secured Note separately as a derivative liability. These agreements included requirements that the Company appoint one designee of Energy Evolution, or its affiliate, to the Board of Directors and appoint that designee, or one of the two designees previously appointed to the Board of Directors by Energy Evolution’s affiliate, the Chairman of the Board of Directors with the power to cast the deciding vote in the event of a deadlocked board vote.
We identified these complex financing transactions as a critical audit matter due to the degree of complexity of the accounting and specialized skills and knowledge required by management’s specialists in order to accurately account for and value the embedded conversion options associated with these transactions. This in turn led to a high degree of auditor subjectivity and judgment, including consultation with Firm specialists, in order to evaluate the audit evidence supporting management’s valuation of the embedded conversion options of both the Secured Note and Amended Secured Note.
The primary procedures we performed to address this critical audit matter included:
| • | Reviewing the underlying agreements and amendments and assessing management’s analysis of the accounting treatment of the original transactions and subsequent amendments. |
| • | Gaining an understanding of management’s valuation estimation process and reviewing management’s specialists’ findings. |
| • | Assessing the qualifications and objectivity of management’s specialists. |
| • | Testing the significant assumptions used by management’s specialists in developing the estimated value of the embedded conversion features, including normalized volatility, risk free rates, expected dividend yields, and the probability of conversion under various scenarios. This included comparing inputs to market data and analyzing conversion probabilities in comparison to economic outcome of each scenario at that time. |
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| • | Utilizing Firm specialists to evaluate accounting treatment as well the accuracy and appropriateness of valuation calculations prepared by management’s specialists. |
| • | Mathematically recalculating the amortization associated with debt discount. |
| • | Evaluating agreements and amendments in order to verify the accuracy and completeness of disclosures and presentation of the related party nature of the Secured Note and the rights granted to Energy Evolution and its affiliates. |
The Impact of Proved Oil Natural Gas Reserves on Depreciation, Depletion, and Amortization (“DDA”) and Impairment Calculations
The Company’s net proved oil and natural gas properties balance was $29,388,408 as of December 31, 2021, and the associated depreciation, depletion and amortization expense for the year ended December 31, 2021 was $2,420,736. The Company recorded no impairment expense for the year ended December 31, 2021. As described in Note 2 of the consolidated financial statements, the Company uses the successful efforts method of accounting for its oil and natural gas activities. Under this method, costs incurred are deferred until exploration and completion results are evaluated, at which time costs of activities associated with economically recoverable reserves are capitalized as proved properties and costs of unsuccessful or uneconomical activities are expensed. Depreciation, depletion, and amortization of producing properties is computed using the units-of-production method. Management’s assessment of the results of exploration activities, commodity price outlooks, planned future sales or expiration of all or a portion of leaseholds impacts the amount and timing of potential impairment provisions.
We identified the impact of proved oil and natural gas reserves on depletion, depreciation, and amortization expense and the carrying value of the oil and gas properties as a critical audit matter due to the use of significant judgment by management, including the use of specialists, when developing the estimates of proved oil and natural gas reserves. This in turn led to a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating audit evidence related to the significant assumptions used in developing those estimates of proved oil and natural gas reserves.
The primary procedures we performed to address this critical audit matter included:
| • | Comparing the significant assumptions used by management in developing the estimates of proved oil and natural gas reserves, including pricing benchmarks to observable market data, and comparing pricing differentials, future operations costs, and future production rates to historical data. |
| • | Evaluating management’s specialists’ qualifications and objectivity, as well as the appropriateness of methods and assumptions used by the specialists in developing the estimates of proved oil and natural gas reserves. The procedures performed included tests of the data used by specialists and an analysis of the specialist’s findings. |
| • | Evaluating the significant assumptions relating to the estimates of proved oil and natural gas reserves and obtaining evidence to support the accuracy of the assumptions, including whether the assumptions used were consistent with the past performance of the Company and evidence obtained in other areas of the audit. |
| • | Testing the inputs and mathematically recalculating management’s depletion and depreciation expense calculation and assessed for compliance with industry and regulatory standards. |
| • | Testing management’s impairment assessment of proved oil and natural gas properties, including management’s cash flows analysis related to the proved oil and natural gas properties. |
| • | Comparing the working and net revenue interests used in the reserve report by testing a sample of land and division order records. |
/s/
Dallas,
March 31, 2022
We have served as the Company’s auditor since 2021.
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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Stockholders and the Board of Directors
of Empire Petroleum Corporation
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheet of Empire Petroleum Corporation (the Company) as of December 31, 2020, the related consolidated statements of operations, stockholders' equity and cash flows for the year then ended, and the related notes to the consolidated financial statements (collectively, the financial statements). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2020, and the results of its operations and its cash flows for the year then ended, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audit. 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 U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit 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. 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 audit 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 audit provides a reasonable basis for our opinion.
/s/ HoganTaylor LLP
We served as the Company’s auditor from 2003 to 2020.
Tulsa, Oklahoma
March 31, 2021
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED BALANCE SHEETS
DECEMBER 31, 2021 AND 2020
| 2021 | 2020 | |||||||
| ASSETS | ||||||||
| Current Assets: | ||||||||
| Cash | $ | $ | ||||||
| Accounts Receivable | ||||||||
| Unrealized Gain on Derivative Instruments | ||||||||
| Inventory | ||||||||
| Prepaids | ||||||||
| Total Current Assets | ||||||||
| Property and equipment: | ||||||||
| Oil and Natural Gas Properties, Successful Efforts | ||||||||
| Less: Accumulated Depreciation, Depletion and Impairment | ( | ) | ( | ) | ||||
| Net | ||||||||
| Other Property and Equipment, net of $ | ||||||||
| Total Property and Equipment, Net | ||||||||
| Unrealized Gain on Derivative Instruments - Long Term | ||||||||
| Sinking Fund | ||||||||
| Utility and Other Deposits | ||||||||
| Total Assets | $ | $ | ||||||
| LIABILITIES AND STOCKHOLDERS' DEFICIT | ||||||||
| Current Liabilities: | ||||||||
| Accounts Payable | $ | |||||||
| Accrued Expenses | ||||||||
| Unrealized Loss on Derivative Instruments | ||||||||
| Contingent Payment | ||||||||
| Current Portion of Lease Liability | ||||||||
| Current Portion of Long-term Notes Payable | ||||||||
| Total Current Liabilities | ||||||||
| Long-Term Notes Payable | ||||||||
| Long Term Lease Liability | ||||||||
| Asset Retirement Obligations | ||||||||
| Total Liabilities | ||||||||
| Stockholders' Equity (Deficit): | ||||||||
| Common Stock - $ Par Value Shares Authorized, | ||||||||
| and Shares Issued and Outstanding, Respectively | ||||||||
| Additional Paid-in Capital | ||||||||
| Accumulated Deficit | ( | ) | ( | ) | ||||
| Total Stockholders' Equity (Deficit) | ( | ) | ||||||
| Total Liabilities and Stockholders' Equity (Deficit) | $ | $ | ||||||
See accompanying notes to consolidated financial statements
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
Years Ended December 31, 2021 and 2020
| 2021 | 2020 | |||||||
| Revenue: | ||||||||
| Oil Sales | $ | $ | ||||||
| Gas Sales | ||||||||
| NGL Sales | ||||||||
| Other | ||||||||
| Net Realized and Unrealized Gain (Loss) on Derivatives | ( | ) | ||||||
| Total Revenue | ||||||||
| Costs and Expenses: | ||||||||
| Operating | ||||||||
| Taxes - Production | ||||||||
| Depletion, Depreciation Amortization | ||||||||
| Impairment of Oil and Natural Gas Properties | ||||||||
| Accretion of Asset Retirement Obligation | ||||||||
| General and Administrative | ||||||||
| Total Cost and Expenses | ||||||||
| Operating Loss | ( | ) | ( | ) | ||||
| Other Income and (Expense): | ||||||||
| Convertible Debt Modification Inducement Expense | ( | ) | ||||||
| Loss on Convertible Debt Redemption Option | ( | ) | ||||||
| Loss on Embedded Conversion Option | ( | ) | ||||||
| Gain on Sale of Assets | ||||||||
| Other Income | ||||||||
| Interest Expense | ( | ) | ( | ) | ||||
| Net Loss | $ | ( | ) | $ | ( | ) | ||
| Net Loss per Common Share, Basic Diluted | $ | ( | ) | $ | ( | ) | ||
| Weighted Average Number of Common Shares Outstanding, | ||||||||
| Basic Diluted | ||||||||
See accompanying notes to consolidated financial statements
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (DEFICIT)
Years ended December 31, 2021 and 2020
| Additional | ||||||||||||||||||||
| Common Stock | Paid-In | Accumulated | ||||||||||||||||||
| Shares | Par Value | Capital | Deficit | Total | ||||||||||||||||
| Balances, December 31, 2019 | $ | $ | $ | ( | ) | $ | ( | ) | ||||||||||||
| Net Loss | — | ( | ) | ( | ) | |||||||||||||||
| Shares, Options, Warrants | ||||||||||||||||||||
| and Conversion Features Issued | ||||||||||||||||||||
| Balances, December 31, 2020 | $ | $ | $ | ( | ) | $ | ( | ) | ||||||||||||
| Net Loss | — | ( | ) | ( | ) | |||||||||||||||
| Stock Compensation Expense | ||||||||||||||||||||
| Stock Options Exercised | ||||||||||||||||||||
| Warrants Exercised | ||||||||||||||||||||
| Issuance of Common Stock and Warrants | ||||||||||||||||||||
| Shares and Warrants Issued for Secured Convertible Note | ||||||||||||||||||||
| Warrants Issued with Unsecured Convertible Notes | — | |||||||||||||||||||
| Right to Buy Issued with Secured Convertible Notes | — | |||||||||||||||||||
| Unsecured Convertible Note Conversion | ||||||||||||||||||||
| Shares Issued for Secured Convertible Note Conversion, Including Payment of Accrued Interest | ||||||||||||||||||||
| Balances, December 31, 2021 | $ | $ | $ | ( | ) | $ | ||||||||||||||
See accompanying notes to consolidated financial statements
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EMPIRE PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
Years ended December 31, 2021 and 2020
| 2021 | 2020 | |||||||
| Cash Flows From Operating Activities: | ||||||||
| Net Loss | $ | ( | ) | $ | ( | ) | ||
| Adjustments to Reconcile Net Loss to Net Cash | ||||||||
| Provided By (Used In) Operating Activities: | ||||||||
| Gain on Sale of Assets | ( | ) | ||||||
| Value of Warrants and Options Granted | ||||||||
| Stock Issued in Lieu of Cash Interest Payment - Senior Secured Convertible Note | ||||||||
| Right to Buy Issuance Costs | 989,115 | — | ||||||
| Loss on Embedded Conversion Option - Senior Secured Convertible Note | ||||||||
| Convertible Debt Modification Inducement Expense | ||||||||
| Amortization of Discount on Convertible Notes | ||||||||
| Amortization of Loan Issue Costs | ||||||||
| Loss on Extinguishment of Debt | ||||||||
| Change in Right of Use Assets, net | ||||||||
| Depreciation, Depletion and Amortization | ||||||||
| Impairment of Oil and Natural Gas Properties | ||||||||
| Accretion of Asset Retirement Obligation | ||||||||
| Paycheck Protection Program Loan Forgiveness | ( | ) | ||||||
| Deposit paid to Ovintiv | ( | ) | ||||||
| Loss Relating to Ovintiv Purchase Deposit | ||||||||
| Change in Operating Assets and Liabilities: | ||||||||
| Accounts Receivable | ( | ) | ( | ) | ||||
| Unrealized Loss on Derivatives | ( | ) | ( | ) | ||||
| Inventory | ( | ) | ||||||
| Prepaids, Current | ( | ) | ||||||
| Other Assets | ( | ) | ||||||
| Accounts Payable | ||||||||
| Accrued Expenses | ||||||||
| Net Cash Provided By (Used In) Operating Activities | ( | ) | ||||||
| Cash Flows from Investing Activities: | ||||||||
| Acquisition of Oil and Natural Gas Properties | ( | ) | ( | ) | ||||
| Purchase of Other Fixed Assets | ( | ) | ( | ) | ||||
| Cash Paid for Right of Use Assets | ( | ) | ||||||
| Sinking Fund Deposit | ( | ) | ||||||
| Proceeds from Sale of Oil and Natural Gas Properties | ||||||||
| Net Cash Provided By (Used In) Investing Activities | ( | ) | ||||||
| Cash Flows from Financing Activities: | ||||||||
| Proceeds from Debt Issued | ||||||||
| Paycheck Protection Program Loan Proceeds | ||||||||
| Principal Payments of Debt | ( | ) | ( | ) | ||||
| Proceeds from Stock and Warrant Issuance | ||||||||
| 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 | $ | $ | ||||||
| Non-cash Investing and Financing Activities: | ||||||||
| Non-cash Additions and Revisions to Asset Retirement Obligations | $ | $ | ||||||
| Common Stock Issued in Exchange for Outstanding Notes Payable | $ | $ | ||||||
| Equipment purchased utilizing note payable | $ | $ | ||||||
| Property additions in notes payable | $ | $ | ||||||
| Purchases of oil and natural gas properties and deposits in accounts and notes payable, accrued expenses, royalty suspense, and contingent payable to seller | $ | $ | ||||||
| Note Payable issued - PIE Agreement (see Note 5) | $ | $ | ||||||
See accompanying notes to consolidated financial statements
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EMPIRE PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
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 has four wholly-owned subsidiaries in its areas of operations:
| ● | Empire North Dakota LLC (“Empire North Dakota”) |
| ● | Empire New Mexico, LLC (“Empire New Mexico”) |
| ● | Empire Texas (“Empire Texas”), consisting of the following entities: |
| o | Empire Texas LLC |
| o | Empire Texas GP LLC |
| o | 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 Utah in August 1983 and subsequently 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.
On August 27, 2021 the Company’s Board of Directors, in conjunction with the majority of the common stock holders, approved a one for four reverse stock split such that every holder of the Company’s common stock shall receive one share of Common Stock for every four shares owned. In addition, the Board authorized the Company to issue ten million shares of no-par value Preferred Stock. As of December 31, 2021, the Company had not made the reverse stock split effective, nor had it issued any Preferred Stock. The reverse stock split was made effective on March 7, 2022, simultaneous with the Company’s listing to the NYSE American. All shares amounts have retrospectively been stated at post-reverse split amounts and pricing.
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 accounting principles generally accepted in the United States (“GAAP”). All intercompany accounts and transactions, including revenues and expenses, have been eliminated in consolidation.
Use of Estimates
The preparation of financial statements in conformity with 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 natural gas liquids (“NGL”) reserves are the most significant of the Company’s estimates. All reserve data used in the preparation of the Consolidated Financial Statements, as well as included in Supplemental Information On Oil And Gas Exploration And Production Activities (Unaudited), are based on estimates. Reservoir engineering is a subjective process of estimating underground accumulations of crude oil, natural gas and NGL. There are numerous uncertainties inherent in estimating quantities of proved crude oil, natural gas and NGL 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 natural gas liquids 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, conversion features on debt convertible, 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.
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Accounts Receivable
Accounts receivable include estimated amounts due from crude oil, natural gas, and NGL 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 withing 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 considered past due if full payment is not received by the contractual due date. Past due accounts are generally written off against the allowance for doubtful accounts only after all collection attempts have been exhausted. The Company did not have an allowance for doubtful accounts at either December 31, 2021 or 2020.
Derivative Instruments
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 value of the outstanding contracts.
Inventory
Inventory consists of oil in tanks which has not been delivered and is valued at the lower of cost or net realizable value.
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 is 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.
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.
Depreciation, 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 depreciation, depletion and amortization computations prospectively.
Other property and equipment is depreciated on the straight-line method.
Segment Reporting
Operating segments are components of an enterprise that engage in activities from which it may earn revenues and incur expenses and for which separate operational financial information is available and is regularly evaluated by management. Based on the Company’s organization and management, it has only one reportable operating segment, which is oil and natural gas exploration and production.
Comprehensive Income
The Company has no elements of comprehensive income other than net income.
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.
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Revenue Recognition
The Company’s revenues are comprised solely of revenues from customers and include the sale of oil, natural gas and NGL. 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 when the recognition criteria of Accounting Standards Codification 606 “Revenue from Contracts with Customers,” (“ASC 606”) are met, which generally occurs at a point in time when production is sold to a purchaser at a determinable price, delivery has occurred, control has transferred and collection of the revenue is probable. The Company fulfills its performance obligations under its customer contracts through delivery of oil, natural gas and NGL and revenues are recorded on a monthly basis and 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 NGL 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 NGL will decrease if market prices decline. The sales of oil, natural gas and NGL, 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 NGL 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 in the Consolidated Balance Sheets. Taxes assessed by governmental authorities on oil, natural gas and NGL sales are presented separately from such revenues in the Consolidated Statements of Operations.
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 NGL 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 NGL sales. Based on the nature of these arrangements, the processor is the agent and the purchaser is the Company’s customer, thus, the Company recognizes natural gas and NGL sales based on the net amount of proceeds received from the purchaser.
Contract Balances
Under the Company’s product sales contracts, the Company invoices customers once performance obligations have been satisfied, at which point payment is unconditional. Accordingly, the Company’s product sales contracts do not give rise to contract assets or liabilities under ASC 606.
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 ASC 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 ASC 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, 2021 and 2020, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material.
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Stock-Based Compensation
The Company recognized stock-based compensation expense associated with granted stock options. The Company 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.
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.
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.
Diluted Earnings per Share ("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 Financial Accounting Standards Board ("FASB") fair value measurement 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 ASC 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 year ended December 31, 2021.
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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 ("NYMEX") 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.
The fair value of asset retirement obligations 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.
Financial instruments and other- The fair values determined for accounts receivable, accrued expenses and other current liabilities were equivalent to the carrying value due to their short-term nature.
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 and published LIBOR forward curves; thus, these inputs are designated as Level 2 within the valuation hierarchy.
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.
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 (“FASB ASC 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
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 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 (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity. 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 Board decided to allow entities to adopt the guidance through either a modified retrospective method of transition or a fully retrospective method of transition. The Company is analyzing the effect that adoption will have but does not expect a material impact as a result of adopting these standards.
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Note 3 – Property
In May 2021 the Company purchased oil and natural gas properties in New Mexico (see Note 4).
The aggregate capitalized costs of oil and natural gas properties as of December 31, 2021 and 2020 are as follows:
| 2021 | 2020 | |||||||
| Proved producing wells | $ | $ | ||||||
| Proved undeveloped | ||||||||
| Lease and well equipment | ||||||||
| Asset retirement obligation | ||||||||
| Gross capitalized costs | ||||||||
| Depreciation, depletion, amortization and impairment | ( | ) | ( | ) | ||||
| Net capitalized costs | $ | $ | ||||||
Other property and equipment consists of operating lease assets, vehicles, office furniture, and equipment with lives ranging from three to five years.
| 2021 | 2020 | |||||||
| Other property and equipment, at cost | $ | |||||||
| Less: accumulated depreciation | ( | ) | ( | ) | ||||
| Oher property and equipment, net | $ | |||||||
Note 4 – Acquisition of XTO Properties
On March 12, 2021 the Company, through its wholly owned subsidiary Empire New Mexico, entered into a purchase and sale agreement with XTO Holdings, LLC (a subsidiary of ExxonMobil) (the “Seller’) to acquire, among other things, certain oil and natural gas properties in New Mexico. The purchase price was $ subject to customary adjustments. The transaction closed on May 14, 2021 with an effective date of January 1, 2021.
The XTO acquisition has been assessed under the screen test for business combinations under FASB ASC 805, Business Combinations (“ASC 805”). The XTO acquisition met the screen test and has been accounted for as an asset acquisition using the acquisition method of accounting. Under the accounting for asset acquisitions, the acquisition is recorded using a cost accumulation and allocation model under which the cost of the acquisition is allocated on a relative fair value basis to the assets acquired and liabilities assumed. Acquisition-related transaction costs are capitalized as a component of the cost of the assets acquired.
As a condition of the sale, the Company purchased
a $
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The following table sets forth the Company's preliminary purchase price allocation:
| Preliminary Fair Value of Assets Acquired | ||||
| Oil and natural gas properties | $ | |||
| Inventory of oil in tanks | ||||
| Vehicles | ||||
| Asset retirement obligations | ||||
| Total preliminary assets acquired | ||||
| Preliminary Fair Value of Liabilities Assumed | ||||
| Royalty suspense | ||||
| Asset retirement obligations | ||||
| Total preliminary liabilities assumed | ||||
| Purchase Price | ||||
The value of oil and gas properties was based on an allocation of the purchase price which included assignment of values to the other identifiable assets acquired and liabilities assumed. The value of inventory, vehicles, and royalty suspense was based on their relative fair values as described above.
The fair value of asset retirement obligations are included in proved oil and natural gas properties with a corresponding liability in the table above. 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.
Final settlement on this acquisition is in process and is expected to occur in 2022.
Note 5 – Joint Development Agreement
On August 6, 2020 the Company, through its
wholly owned subsidiary, Empire Texas, entered into a joint development agreement (the “JDA”) with Petroleum Independent
Exploration, LLC and related entities (“PIE”), a related party (See Note 12), dated August 1, 2020. Under the terms of the
JDA, PIE will perform recompletion or workover on specified mutually agreed upon wells (“Workover Wells”) owned by Empire
Texas. To fund the work, PIE entered into a term loan agreement with Empire Texas dated August 1, 2020, whereby PIE will loan up to $
In addition, PIE and Empire entered into a
Securities Purchase Agreement (“Securities Agreement”) whereby
Note 6 - 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. 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.
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The Company’s asset retirement obligation transactions during the years ended December 31, 2021 and 2020 are summarized in the table below.
| For the Year Ended December 31, | ||||||||
| 2021 | 2020 | |||||||
| Asset retirement obligations, beginning of period | $ | $ | ||||||
| Liabilities assumed in acquisitions | ||||||||
| Revision to estimates | ( | ) | ( | ) | ||||
| Accretion expense | ||||||||
| Asset retirement obligation, end of period | $ | $ | ||||||
Note 7 – Commodity Derivative Financial Instruments
The Company uses derivative financial instruments to manage its exposure to commodity price fluctuations. Commodity derivative instruments are 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 instruments consist of 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. Unrealized gains and losses related to the contracts are recognized and recorded as an asset or liability on the Company’s consolidated balance sheets.
The following table summarizes the net realized and unrealized amounts reported in earnings related to the commodity derivative instruments for the years ended December 31, 2021 and 2020:
| For the Year Ended December 31, | ||||||||
| 2021 | 2020 | |||||||
| Gain (loss) on derivatives: | ||||||||
| Oil derivatives | $ | ( | ) | $ | ||||
The following represents the Company’s net cash receipts from (payments on) derivatives for the years ended December, 2021 and 2020:
| For the Year Ended December 31, | ||||||||
| 2021 | 2020 | |||||||
| Oil derivatives | $ | ( | ) | $ | ||||
| Natural gas derivatives | ( | ) | ||||||
| Total | $ | ( | ) | $ | ||||
The following table sets forth the Company’s outstanding derivative contracts at December 31, 2021:
| 1st Quarter | 2nd Quarter | 3rd Quarter | 4th Quarter | ||||
| 2022 | |||||||
| WTI Index Put Options: | |||||||
| Quarterly volume (MBbl) | |||||||
| Floor Price (Bbl) | $ |
$ |
$ |
$ |
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| 1st Quarter | 2nd Quarter | 3rd Quarter | |||||
| 2023 | |||||||
| WTI Index Put Options: | |||||||
| Quarterly volume (MBbl) | |||||||
| Floor Price (Bbl) | $ |
$ |
$ |
Note 8 - Debt
The following table represents the Company’s outstanding debt.
| December 31, | ||||||||
| 2021 | 2020 | |||||||
| Senior Revolver Loan Agreement | $ | $ | ||||||
| Term Loan – PIE | ||||||||
| Equipment and vehicle notes, | ||||||||
| Unsecured Note, Pardus Acquisition | ||||||||
| Note Payable to Insurance Provider, bears | ||||||||
| SBA Payroll Protection Program Note Payable | ||||||||
| Total Debt | ||||||||
| Unamortized debt issue costs | ||||||||
| Total debt, net of debt issue costs | ||||||||
| Less Current Maturities | ||||||||
| Total Long-Term Debt | $ | $ | ||||||
On July 7, 2021 the Company entered into the
Fourth Amendment to its Senior Revolver Loan Agreement (“the Amended Agreement”) with CrossFirst Bank (“CrossFirst”).
The maximum amount that can be advanced under the Agreement is $20,000,000 and the existing commitment amount is $
In August 2020, concurrent with the Joint Development
Agreement with Petroleum and Independent Exploration, LLC (“PIE”), a related party, the Company entered into a term loan
agreement dated August 1, 2020, whereby PIE will loan up to $
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On April 1, 2020, in conjunction with the purchase
of assets from Pardus Oil Gas, LLC, the Company entered into an unsecured promissory note agreement with the seller in the amount
of $
On May 5, 2020, the Company received an SBA
Payroll Protection Plan (“PPP”) loan for $
On April 30, 2021 the Company received a Second
Draw SBA “PPP” loan for $
Note 9 – Convertible Notes Payable
Senior Secured Note Agreement
On May 14, 2021, the Company’s wholly
owned subsidiary, Empire New Mexico entered into a Senior Secured Convertible Note Agreement (the “Secured Note”) in the
amount of $
As partial consideration for the issuance of
the Secured Note, Energy Evolution received a closing fee of shares of the Company’s common stock and warrants to purchase
On September 29, 2021 the parties entered into
a Loan Modification Agreement (the “Amended Secured Note”) pursuant to which Energy Evolution exchanged $
Pursuant to the Amended Secured Note, the Company’s obligations with respect to a registration statement under the Secured Note were extended, the Company executed and delivered a Pledge and Security Agreement granting Energy Evolution a first priority perfected security interest in the Company’s membership interest in Empire New Mexico, d/b/a Green Tree New Mexico, the Company and Green Tree New Mexico agreed to use commercial reasonable best efforts to separate Green Tree New Mexico from the Company as an independent business on or before December 31, 2022 in a spin-off to stockholders of the Company. In accordance with ASC 470-20, the Company accounted for this exchange as an induced conversion based on the short period time of the offer was open and the substantive conversion feature offer. The Company accounted for the conversion of the
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debt
instruments as an inducement by expensing the fair value of the instruments that were issued in excess of the original terms of the Secured
Notes. The Company reduced the outstanding debt by $
On December 30, 2021, the Company amended the
Amended Secured Note to allow full conversion of the remaining principal and accrued interest at that date. $
Unsecured Convertible Notes
In May 2021 the Empire New Mexico entered
into $
The Company determined the embedded conversion
features of the Unsecured Notes were equity-classified financing instruments. The fair value of the conversion feature was determined
using a beneficial conversion model based on a 60-day weighted average stock price and the maximum number of shares to be received if
converted. As issuance, the amount recorded to additional paid in capital was $
As an inducement for investors to enter
into the Unsecured Convertible Notes, the Company’s Chief Executive Officer and President collectively offered to each investor
the right to purchase a number of shares of common stock equal to
Note 10 - Leases
As a lessee, the Company leases its corporate office headquarters in Tulsa, Oklahoma and three field offices. The leases expire between 2024 and 2027. The corporate office has an option to renew for an additional five-year term. The option to renew the lease is generally not considered reasonably certain to be exercised. Therefore, the period covered by such optional period is not included in the determination of the term of the lease and the lease payments during these periods are similarly excluded from the calculation of right-of-use lease asset and lease liability balances.
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 $
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Supplemental balance sheet information related to the right of use leases as of December 31, 2021 is as follows:
| 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.
| 2022 | $ | ||||
| 2023 | |||||
| 2024 | |||||
| 2025 | |||||
| 2026 | |||||
| Thereafter | |||||
| Total lease payments | |||||
| Less imputed interest | ( | ) | |||
| Total lease obligation | $ |
Note 11 – Equity
Diluted Earnings per Share (“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. At December 31, 2021 and 2020, the Company had and options outstanding that were not included in the calculation of earnings per share for the periods then ended. Such financial instruments may become dilutive and would then need to be included in future calculations of Diluted EPS.
On August 7, 2020 concurrently with the Joint Development Agreement
with Petroleum Independent Exploration, LLC and related entities (“PIE”), the companies entered into a Securities Purchase
Agreement (“Securities Agreement”) whereby
During February and March 2021, the Company issued
to a group of accredited investors shares of its common stock and warrants to purchase shares of its common stock
for $ per share which expires on
In connection with the purchase of
XTO assets the Company issued a Senior Secured Convertible Note due
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Additionally, in conjunction with the purchase of
XTO assets, the Company entered into $
On April 3, 2019, the Board of Directors
of the Company adopted the Empire Petroleum Corporation 2019 Stock Option Plan (the “Stock Option Plan”). The
total number of shares of common stock that may be issued pursuant to stock options under the Stock Option Plan is 2,500,000. Further, on April 3, 2019 the Company granted Mr. Pritchard and Mr. Morrisett each, options to purchase
shares of common stock of the Company at an exercise price of $
On August 27, 2021, the Board of Directors of the Company adopted
the Empire Petroleum Corporation 2021 Incentive Plan (the “Incentive Plan”). The total number of shares of common stock that
may be issued pursuant to the Incentive Plan is three million. As of December 31, 2021, grants were made amounting to
| Weighted Average | ||||||||
| Options | Exercise Price | |||||||
| Outstanding at December 31, 2019 | $ | |||||||
| Granted | ||||||||
| Expired | ( | ) | ||||||
| Outstanding at December 31, 2020 | $ | |||||||
| Granted | ||||||||
| Exercised | ( | ) | ||||||
| Outstanding at December 31, 2021 | $ | |||||||
The following table summarizes information about stock options outstanding at December 31, 2021:
| Options Outstanding | Options Exercisable | |||||||||
| Weighted | ||||||||||
| Average | Weighted | Weighted | ||||||||
| Range of | Number | Remaining | Average | Average | ||||||
| Exercise | Outstanding | Contractual | Exercise | Exercise | ||||||
| Prices | at 12/31/21 | Life | Price | Exercisable | Price | |||||
| $ |
$ |
$ | ||||||||
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Note 12 – Income Taxes
The current income tax provision and deferred income tax provision for the years ended December 31, 2021 and 2020 were comprised for the following:
| 2021 | 2020 | |||||||
| Expected tax benefit | $ | ( | ) | $ | ( | ) | ||
| Nondeductible expenses | ||||||||
| Increase in valuation allowance | ||||||||
| Tax provision (benefit) as reported | $ | $ | ||||||
At December 31, 2021, the Company had
net operating loss carryforwards of approximately $
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 nettax position as of December 31, 2021 and 2020 is as follows :
| 2021 | 2020 | |||||||
| Deferred tax assets (liabilities): | ||||||||
| Loss carry-forwards | $ | $ | ||||||
| Depreciation, depletion and impairment | ||||||||
| Right of use assets | ||||||||
| Stock option grants | ||||||||
| Other property and equipment | ( | ) | ||||||
| Unrecognized losses on derivatives | ||||||||
| Total deferred tax assets | ||||||||
| Valuation allowance | ( | ) | ( | ) | ||||
| Net deferred taxes | $ | $ | ||||||
Reconciliations of the tax expense (benefit) computed at the statutory federal rate to the Company’s total income tax benefit for the years ended December 31, 2021 and 2020 are as follows:
| 2021 | 2020 | |||||||||||||||
| $ | % | $ | % | |||||||||||||
| Pretax GAAP Loss | ( | ) | — | ( | ) | — | ||||||||||
| Pretax GAAP Loss at Statutory Rate | ( | ) | ( | ) | ||||||||||||
| State Taxes | ( | ) | ( | ) | ||||||||||||
| Nondeductible Expenses | - | — | ||||||||||||||
| Valuation Allowance | -7.0% | -25.8% | ||||||||||||||
| Effective | ||||||||||||||||
Utilization of the Company’s loss carryforwards is dependent on realizing taxable income. The Company recorded valuation allowances as of December 31, 2021 and 2020 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.
The Company has evaluated all tax positions for which the statute of limitations remains open and believes that the material positions taken would likely than not would be sustained by examination. Therefore, at December 31, 2021, the Company has not established any reserves for, nor recorded any unrecognized benefits related to uncertain tax positions.
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Note 13 – Related Party Transactions
The Energy Evolution Master Fund, Ltd. (“Energy
Evolution”) is a related party of the Company as it beneficially owns approximately
In March 2021, the majority owner of PIE, through
the exercise of warrants, became a significant shareholder of the Company’s outstanding shares of stock (See Note 11). The Company
has a joint development agreement with PIE to perform recompletion or workover on specified mutually agreed upon wells (See Note 5).
As of December 31, 2021, the Company has incurred obligations of approximately $
Note 14 – 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.
The Company is undergoing a sales tax audit related to its Texas entity. No formal assessment has been
provided to the Company. The maximum exposure of this sales tax assessment is approximately $
Note 15 – 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, 2021, the Company sold
Note 16 – Subsequent Events
The Company uplisted from the OTCQB to the NYSE American effective March 8, 2022. Immediately prior to
the listing, a reverse stock split of
On February 28, 2022, the Company granted approximately
stock options under the 2021 Stock Option and Incentive plan to management and employees of the Company.
The Company named Eugene J. Sweeney as Chief Operating Officer in March 2022. Mr. Sweeney previously served as the Company’s Vice President of Operations from May 2021 to the date of his promotion.
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EMPIRE PETROLEUM CORPORATION
Supplemental Information “Oil and Natural Gas Producing Activities (Unaudited)
December 31, 2021 and 2020
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
Capitalized costs include the cost of properties, equipment, and facilities for oil and natural gas producing activities. Capitalized costs for proved properties includes costs for oil and natural gas leaseholds where proved reserves have been identified and non-operated development wells and related equipment and facilities.
| Years Ended December 31, | ||||||||
| 2021 | 2020 | |||||||
| Proved acquisition costs | $ | 23,780,111 | $ | 10,913,393 | ||||
| Revisions to abandonment costs | (1,547,640 | ) | (862,405 | ) | ||||
| Development costs | 1,970,410 | — | ||||||
| Total additions | $ | 24,202,881 | $ | 10,050,988 | ||||
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 expenditures is required for recompletion. Below are the net quantities of net proved developed reserves of the Company’s properties:
| Oil (MMBbls) | Gas (MMcf) | MBOE | ||
| Balance, December 31, 2019 | 3,643 | 404 | 3,710 | |
| Acquisition of Reserves | 580 | 1,092 | 762 | |
| Revisions | (397) | (385) | (461) | |
| Production | (165) | (140) | (188) | |
| Balance, December 31, 2020 | 3,661 | 971 | 3,823 | |
| Acquisition of Reserves | 5,634 | 10,533 | 7,390 | |
| Revisions | (617) | 251 | (576) | |
| Extensions | 150 | 51 | 159 | |
| Divestiture of Reserves | (47) | 27 | (42) | |
| Production | (333) | (625) | (437) | |
| Total Reserves | 8,449 | 11,208 | 10,317 |
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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 Financial Accounting Standard Board ASC 932-235-555. 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:
| December 31, | ||||||||
| Description | 2021 | 2020 | ||||||
| Future cash inflows | $ | 627,654,125 | $ | 121,959,450 | ||||
| Future production costs | (362,254,813 | ) | (55,350,840 | ) | ||||
| Future development costs | (33,021,749 | ) | (1,682,210 | ) | ||||
| Future income tax expense | (30,614,383 | ) | — | |||||
| Future net cash flows | 201,763,180 | 64,926,400 | ||||||
| 10% annual discount for estimated timing of cash flows | (107,911,087 | ) | (44,156,400 | ) | ||||
| Standardized measure | $ | 93,852,093 | $ | 20,770,000 | ||||
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:
| 2021 | 2020 | |||||||
| Oil (BBl) | $ | 64.31 | $ | 32.94 | ||||
| Natural gas (MMBtu) | $ | 7.34 | * | $ | 1.41 | |||
*Pricing includes revenue received from NGL sales as well as natural gas.
Changes in the Standardized Measure of Discounted Future Net Cash Flows at 10% per annum are as follows:
| December 31, | ||||||||
| Description | 2021 | 2020 | ||||||
| Beginning of year | $ | 20,770,080 | $ | 37,301,920 | ||||
| Net change in prices and production costs | 13,080,689 | (18,386,232 | ) | |||||
| Net change in future development costs | 782,210 | 16,937,402 | ||||||
| Oil Gas net revenue | (10,587,395 | ) | (2,164,496 | ) | ||||
| Extensions | 5,026,479 | — | ||||||
| Acquisition of reserves | 90,104,017 | 13,694,856 | ||||||
| Divestiture of reserves | (318,813 | ) | — | |||||
| Revisions of previous quantity estimates | (3,794,860 | ) | (4,348,703 | ) | ||||
| Net change in taxes | (15,544,094 | ) | — | |||||
| Accretion of discount | 2,077,008 | 5,099,678 | ||||||
| Changes in timing and other | (7,743,228 | ) | (27,364,345 | ) | ||||
| End of year | $ | 93,852,093 | $ | 20,770,080 | ||||
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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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