Item 1. Business
ITEM 1. BUSINESS.
In this Form 10-K, references to “Empire”,
the “Company”, “we”, “our”, and “us” refer to Empire Petroleum Corporation and its wholly-owned
subsidiaries, unless context indicates otherwise.
On March 8, 2022, our common stock began trading on
the NYSE American under the symbol “EP” and CUSIP 292034303. Prior to trading on the NYSE American, our common stock was accessible
on the OTCQB.
Overview
Empire Petroleum Corporation is an independent
energy company that engages in unlocking value in developed assets. Empire operates the following wholly-owned subsidiaries in its areas
of operations:
• Empire
New Mexico LLC (“Empire New Mexico”)
○ Empire
New Mexico LLC d/b/a Green Tree New Mexico
○ Empire EMSU LLC
○ Empire EMSU-B LLC
○ Empire AGU LLC
○ Empire NM Assets LLC
• Empire
Rockies Region
○ Empire
North Dakota LLC (“Empire North Dakota”)
○ Empire
ND Acquisition LLC (“Empire NDA”)
• Empire
Texas (“Empire Texas”), consisting of the following entities:
○ Empire
Texas LLC
○ Empire
Texas Operating LLC
○ Empire
Texas GP LLC
○ Pardus
Oil & Gas Operating, LP (owned 1% by Empire Texas GP LLC and 99% by Empire Texas LLC)
• Empire
Louisiana LLC (“Empire Louisiana”)
Empire was incorporated in the state of Delaware in
1985. The consolidated financial statements of Empire Petroleum Corporation and subsidiaries include the accounts of the Company and its
wholly-owned subsidiaries.
Our mission is to increase shareholder value by building
oil and natural gas reserves in strategic plays in the United States. To accomplish its mission, we plan on executing the following business
strategies:
· Cost-effectively optimize well production
· Reduce unit operating costs and improve margins
· Target proved developed producing acquisitions in predictable fields that have historically had low
production decline and long lives
· Focus on high-quality assets that add scale and provide synergies to our existing portfolio and core
areas of operation
We operate as a single segment as each of our operating
areas have similar economic characteristics and each meet the criteria for aggregation as defined by accounting standards related to disclosures
about segments of an enterprise.
Available Information
Our Annual Report on Form 10-K, quarterly reports
on Form 10-Q, current reports on Form 8-K and all amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d)
of the Exchange Act, as well as proxy statements and other information we file with, or furnish to, the SEC are available free of charge
on our website at www.empirepetroleumcorp.com. We make these documents available as soon as reasonably practicable after we electronically
file them with, or furnish them to, the SEC. The information contained on our website, or available by hyperlink from our website, is
not incorporated into this Form 10-K or other documents we file with, or furnish to, the SEC. We intend to use our website as a means
of disclosing material non-public information and for complying with our disclosure obligations under Regulation FD. Such disclosures
will be included on our website in the “Investor Relations” sections. Accordingly, investors should monitor such portions
of our website, in addition to following our press releases, SEC filings and public conference calls and webcasts.
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In addition, we use social media to communicate with
our investors and the public about our company, our businesses and our results of operations. The information we post on social media
could be deemed to be material information. Therefore, we encourage investors, the media and others interested in our company to review
the information we post on the social media channels listed in the “Investor Relations” section of our website.
Properties
We are an independent operator in four geographic
areas in the United States. As operator, we manage and influence production on operated properties. We use a combination of experienced
field personnel and third-party service providers to execute our mission. Our producing properties have reasonably predictable production
profiles and cash flows, subject to commodity price and cost fluctuations.
As is common in the industry in which we operate,
we selectively participate in drilling and developmental activities in non-operated properties. Decisions to participate in non-operated
properties are made after technical and economic analysis of the projects which also considers the operating expertise and historical
track record of the operators.
Empire New Mexico
Empire New Mexico was formed when we purchased
producing assets from XTO in May 2021. These assets are located in Lea County, New Mexico and include approximately 670 gross (483 net)
producing and injection wells on a contiguous and consolidated acreage position consisting of 48,000 gross (41,000 net). We also have
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
· Blineberry
· Tubb
· Drinkard
We have begun technical work for uplift opportunities
in New Mexico.
Empire North Dakota
Empire North Dakota includes approximately 138
gross (108 net) producing or injection wells on 24,000 gross (18,000 net) acres in North Dakota and western Montana. We also have smaller
nonoperating interests in 70 gross (less than 1 net) vertical wells. 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
The existing producing properties have experienced
near-flat production rates over the last five years. We have been able to capitalize on operational improvements to allow more immediate
recovery of reserves.
In the fourth quarter of 2023,
the Company commenced a program to further develop its Starbuck Field located in North Dakota (the “Starbuck Drilling Program”).
Empire expects 2024 to be a year of progress as it continues to advance the Starbuck Drilling Program.
The Starbuck Drilling Program’s
first well came online in December 2023 and a total of five wells in the Upper Charles formation have been placed on production as of
the filing date of this report. The Company is currently optimizing completions while increasing the core production through its enhanced
oil recovery (“EOR”) program.
The Company currently has one
rig in the Starbuck Field. As the Starbuck Field is strategically designed for EOR production, the Company anticipates EOR development
to begin in the second quarter of 2024 with the goal of providing a meaningful increase in production beginning as soon as the second
half of 2024 and going forward.
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Empire has also logged five
vertical pilot wells to help identify additional pay and extend existing reservoirs, which has confirmed three additional primary zones
of interest and two secondary zones of interest. In addition, the Company has drilled a vertical appraisal well in the Starbuck Field
to core two new target zones for development. The two new primary target zones of development have been successfully cored and the cores
are under analysis. The data will then be added to the development plan while the vertical well will be placed on production in the first
quarter of 2024.
Empire Texas
Empire Texas includes approximately 121 gross (106
net) producing wells on approximately 43,000 gross (30,000 net) acres as well as 77 miles of gathering lines and pipelines with related
facilities and equipment. Empire Texas owns concentrated acreage and stacked pay in the historically prolific East Texas Basin. Assets
are concentrated in the Fort Trinidad Field in Houston and Madison Counties with high working interest and historical production from
eight separate formations. We have begun technical work for uplift opportunities in Texas.
Empire Louisiana
Empire Louisiana includes 12 gross (10 net) producing wells and three saltwater
disposal wells in the Miocene, Frio, Cockfield, and Wilcox formations. Empire Louisiana’s assets primarily produce oil.
Production and Operating Data
The following table sets forth a summary of our production
and operating data for the years ended December 31, 2023 and 2022. 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, 2023
Year Ended
December 31, 2022
Production and operating data:
Net sales volumes:
Oil (Bbl)
487,869
482,818
Natural gas (Mcf)
854,274
875,647
Natural gas liquids (Bbl)
136,013
160,809
Total (Boe)
766,261
789,568
Average price per unit:
Oil (a)
$ 75.19
$ 93.16
Natural gas
$ 2.02
$ 5.18
Natural gas liquids
$ 12.21
$ 22.76
Total (Boe)
$ 52.29
$ 67.34
Operating costs and expenses per Boe:
Lease operating expense (excluding workovers)
$ 21.70
$ 19.92
Workovers
$ 15.66
$ 9.95
Total Lease operating expense
$ 37.36
$ 29.87
Production and ad valorem taxes
$ 3.97
$ 4.99
Depreciation, depletion, amortization and accretion
$ 6.33
$ 4.19
General & administrative (excluding stock-based compensation)
$ 15.71
$ 12.18
Stock-based compensation
$ 4.10
$ 3.44
(a) Excludes the effect of net cash receipts from (payments on) derivatives.
At December 31, 2023 and 2022, we had approximately
1,000 gross (710 net) producing and injection wells.
We have no firm delivery commitments for oil or natural
gas.
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Oil and Natural Gas Reserves
Our primary mission is to optimize existing producing
properties; as such, there are no reserves estimated for undeveloped properties, though we own acreage that can be drilled in the future
and are also a non-operator WI owner on acreage subject to future drilling activities. The following table represents our oil and natural
gas reserves at December 31, 2023 and 2022.
Oil
Natural Gas
NGL
(Mbbl)
(MMcf)
(Mbbl)
MBoe
Proved developed at December 31, 2023
6,924
6,104
1,171
9,112
Proved developed at December 31, 2022
8,826
12,936
2,262
13,244
Net proved reserves were calculated using an unweighted
arithmetic average of the first-day-of-the-month price within the 12-month period for the year. All prices and costs associated with operating
wells were held constant in accordance with SEC guidelines. Prices of $75.45 per barrel of oil, $1.51 per Mcf and $9.82 per barrel of
NGL were utilized at December 31, 2023. Prices of $91.14 per barrel and $4.23 per Mcf and $36.29 per barrel of NGL were utilized at December
31, 2022.
Reserve Estimation Process
Reserve estimation is a subjective process as the
underground accumulations of crude oil and natural gas cannot be measured in an exact manner, and the accuracy of any reserve estimate
is a function of the quality of available data and of engineering and geological interpretation and judgment. 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 our external engineers to ensure the integrity, accuracy, and
timeliness of data that is furnished to them for their reserve estimation process.
We engage an independent petroleum engineering firm,
CG&A, to prepare our annual reserve estimates and rely on CG&A’s expertise to ensure that reserve estimates are prepared
in accordance with SEC guidelines.
The technical person primarily responsible for the
preparation of the reserve report is Zane Meekins, Executive Vice President. Mr. Meekins has been with CG&A since 1989 and graduated
from Texas A&M University in 1987 with a bachelor's degree in Petroleum Engineering. He is a registered professional engineer in Texas
and has more than 30 years of experience in the estimation and evaluation of oil and natural gas reserves. He is also a member of the
Society of Petroleum Engineers and the Society of Petroleum Evaluation Engineers.
Brian Weatherl, Vice President of Engineering for
the Company, is responsible for our reservoir engineering, and is a qualified reserve estimator and is responsible for overseeing CG&A
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 primary inputs to the reserve estimation process
are technical information, financial data, ownership interest and production data. The relevant field and reservoir technical information,
which is updated at least annually, is assessed for validity when CG&A has technical meetings with our personnel. 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. 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. Our 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 our 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, CG&A
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 CG&A so that it can prepare its independent reserve estimate and final
report. The reserve estimates prepared by CG&A are reviewed and compared to internal estimates by Mr. Weatherl. Material reserve estimation
differences are reviewed between CG&A and our technical personnel and additional data is provided to address any variances. If the
supporting documentation does not justify additional changes, CG&A reserves are accepted. In the event that additional data supports
a reserve estimation adjustment, CG&A 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 CG&A.
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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 primarily 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 2023, 70% of revenues from oil, natural gas, and
NGL sales were to three customers. For 2022, 68% of revenues from oil, natural gas, and NGL sales were to four customers. While the loss
of these purchasers may result in a temporary interruption in sales of, or a lower price for, our production, we believe that the loss
of these purchasers would not have a material adverse effect on our operations, as there are alternative purchasers in our producing regions.
Competition
The oil and natural gas industry in the areas in which
we operate is highly competitive. We encounter strong competition from numerous parties, ranging generally from small independent producers
to major integrated companies. We primarily encounter significant competition in acquiring properties. At higher commodity prices, we
also face competition in contracting for oil field services, rigs, pressure pumping and workover equipment and securing trained personnel.
Many of these competitors have financial, technical and personnel resources substantially larger than ours. As a result, our competitors
may be able to pay more for desirable properties, or to evaluate, bid for and purchase a greater number of properties or prospects than
our financial or personnel resources will permit.
In addition to competition for drilling, pressure
pumping and workover equipment, we are also affected by the availability of related equipment and materials. The oil and natural gas industry
periodically experiences shortages of drilling and workover rigs, equipment, pipe, materials and personnel, which can delay workover and
exploration activities and cause significant price increases. We are unable to predict the timing or duration of any such shortages.
Seasonality of Business
Weather conditions often affect the demand for, and
prices of, natural gas and can also delay oil and natural gas production. Demand for natural gas is traditionally higher in the winter,
resulting in higher natural gas prices during the first and fourth quarters. Due to these seasonal fluctuations, results of operations
for individual quarterly periods may not be indicative of the results realized on an annual basis.
Markets and Price Volatility
The market price of oil and natural gas is volatile,
subject to speculative movement and depends upon numerous factors beyond our control, including expectations regarding inflation, global
and regional demand, political and economic conditions and production costs. Future profitability, if any, will depend substantially upon
the prevailing prices for oil and natural gas. If the market price for oil and natural gas remains depressed in the future, it could
have a material adverse effect on our ability to raise additional capital necessary to finance operations. Lower oil and natural gas prices
may also reduce the amount of oil and natural gas, if any, that can be produced economically from our properties. We anticipate
that the prices of oil and natural gas will fluctuate in the near future.
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Regulation
The oil and natural
gas industry is subject to extensive federal, state and local laws and regulations governing the production, transportation and sale
of hydrocarbons as well as the taxation of income resulting therefrom. Legislation affecting the oil and natural gas industry is constantly
changing. Numerous federal and state departments and agencies have issued rules and regulations applicable to the oil and natural
gas industry. In general, these rules and regulations regulate, among other things, the extent to which
acreage may be acquired or relinquished; spacing of wells; measures required for preventing waste of oil and natural gas resources; and,
in some cases, rates of production. The heavy and increasing regulatory burdens on the oil and natural gas industry increase our
cost of doing business and, consequently, affect profitability.
Our oil and natural
gas operations are also subject to numerous federal, state and local laws and regulations relating to environmental protection. These
laws govern, among other things, the amounts and types of substances and materials that may be released into the environment, the issuance
of permits in connection with exploration, drilling and production activities, the reclamation and abandonment of wells and facility
sites and the remediation of contaminated sites. These laws and regulations may impose substantial liabilities if we fail to comply
or if any contamination resu lts from our operations.
Employees
At December 31, 2023, we had 50 full-time employees,
not including contract personnel and outsourced service providers. Our team is broadly experienced in oil and natural gas operations and
follows a strategy of outsourcing most accounting, human resources, and other non-core functions.
Office Locations
Our corporate headquarters are at 2200 South Utica
Place, Suite 150, Tulsa, Oklahoma, with field offices in North Dakota, Texas, and New Mexico.
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