NOTES
TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
1.
ORGANIZATION, OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES
Organization
and Operations
U.S.
Energy Corp. (collectively with its wholly-owned subsidiaries, Energy One LLC (“Energy One”) and New Horizon Resources
LLC (“New Horizon Resources”), referred to as the “Company” in these Notes to Unaudited Condensed
Consolidated Financial Statements) is incorporated in the State of Delaware. The Company’s principal business activities are
focused on the acquisition, exploration and development of oil and natural gas properties in the United States.
Basis
of Presentation
The
accompanying unaudited condensed consolidated financial statements are presented in accordance with U.S. generally accepted
accounting principles (“GAAP”) and have been prepared by the Company pursuant to the rules and regulations of the
Securities and Exchange Commission (the “SEC”) regarding interim financial reporting. Accordingly, certain information
and footnote disclosures required by GAAP for complete financial statements have been condensed or omitted in accordance with such
rules and regulations. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered
necessary for a fair presentation of the condensed consolidated financial statements have been included.
For
further information, refer to the consolidated financial statements and footnotes thereto included in our Annual Report on Form 10-K
for the year ended December 31, 2022, as filed with the SEC on April 13, 2023. Our financial condition as of March 31, 2023, and operating
results for the three months ended March 31, 2023, are not necessarily indicative of the financial condition and results of operations
that may be expected for any future interim period or for the year ending December 31, 2023.
Use
of Estimates
The
preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported
amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported
amounts of revenues and expenses during the reporting period. Significant estimates include the fair value of oil and gas properties
acquired, oil and natural gas reserves that are used in the calculation of depreciation, depletion, amortization and impairment of the
carrying value of evaluated oil and natural gas properties; realizability of unevaluated properties; production and commodity price estimates
used to record accrued oil and natural gas sales receivables; future prices of commodities used in the valuation of commodity derivative
contracts; and the cost and timing of future asset retirement obligations. The Company evaluates its estimates on an on-going basis and
bases its estimates on historical experience and on various other assumptions the Company believes to be reasonable. Due to inherent
uncertainties, including the future prices of oil and natural gas, these estimates could change in the near term and such changes could
be material.
Recently
Adopted Accounting Standards
On January 1, 2023, the Company adopted ASU 2016-13 to Topic
326, Financial Instruments-Credit Losses, as amended by other related ASUs that provided targeted improvements. The standard
changes the impairment model for trade receivables and other financial assets measured at amortized cost. This ASU requires the use of
a new forward-looking “expected loss” model compared to the previous “incurred loss” model, resulting in accelerated
recognition of credit losses. This ASU primarily applies to the Company’s accounts receivable balances, of which the majority
are received within a short-term period of one to three months. The Company monitors the credit quality of its counterparties through
review of collections, credit ratings, and other analyses. The Company develops its estimated allowance for credit losses primarily using
an aging method and analyses of historical loss rates as well as consideration of current and future conditions that could impact its
counterparties’ credit quality and liquidity. The adoption and implementation of this ASU did not have a material impact on the
Company’s financial statements.
Industry
Segment and Geographic Information
The
Company operates in the exploration and production segment of the oil and gas industry, onshore in the United States. The Company reports
as a single industry segment.
Principles
of Consolidation
The
accompanying financial statements include the accounts of U.S. Energy Corp. and its wholly-owned subsidiaries Energy One and New Horizon
Resources. All inter-company balances and transactions have been eliminated in consolidation.
2.
ACQUISITIONS
January
2022 Acquisition
On
January 5, 2022 (the “Closing Date”), the Company closed the acquisitions (the “Acquisition”) contemplated by
three separate Purchase and Sale Agreements (the “Purchase Agreements” and the “Closing”), entered into by the
Company on October 4, 2021, with each of (a) Lubbock Energy Partners LLC (“Lubbock”); (b) Banner Oil & Gas, LLC, Woodford
Petroleum, LLC and Llano Energy LLC (collectively, “Banner”), and (c) Synergy Offshore LLC (“Synergy”, and collectively
with Lubbock and Banner, the “Sellers”). Pursuant to the Purchase Agreements, the
Company acquired certain oil and gas properties from the Sellers, representing a diversified portfolio of primarily operated, producing,
oil-weighted assets located across the Rockies, West Texas, Eagle Ford, and Mid-Continent. The acquisition also included certain wells,
contracts, technical data, records, personal property and hydrocarbons associated with the acquired assets (collectively with the oil
and gas properties acquired, the “Acquired Assets”).
The
Company accounted for the acquisition of the Acquired Assets as an asset acquisition. The purchase price for the Acquired Assets was
(a) $125,000 in cash and 6,568,828 shares of our common stock, as to Lubbock; (b) $1,000,000 in cash, the assumption of $3.3 million
of debt, and 6,790,524 shares of common stock, as well as the novation of certain hedges which had a mark to market loss of approximately
$3.1 million as of the Closing Date, as to Banner; and (c) $125,000 in cash and 6,546,384 shares of common stock, as to Synergy. The
aggregate purchase price under all the Purchase Agreements was $66.4 million, representing $1.25 million in cash, the value of 19,905,736
shares of our common stock on the Closing Date of $64.7 million and purchase price adjustments of $0.5 million. In addition, we assumed
various liabilities, including the repayment of $3.3 million in debt, as well as a derivative liability from the novation of the hedges
discussed above of $3.1 million, suspense accounts and asset retirement obligations.
SUMMARY OF AMOUNTS INCURRED FOR ASSETS ACQUIRED
| |
Amount | |
| |
(in thousands) | |
Amounts incurred: | |
| | |
Cash | |
$ | 1,250 | |
Value of 19,905,736 shares issued | |
| 64,694 | |
Purchase price adjustments | |
| 487 | |
Transaction
costs | |
| 1,267 | |
Total
consideration paid | |
| 67,698 | |
| |
| | |
Debt assumed | |
| 3,347 | |
Commodity derivative liabilities
assumed | |
| 3,152 | |
Suspense accounts assumed | |
| 1,276 | |
Employee obligations assumed | |
| 100 | |
Asset retirement obligations
assumed | |
| 9,614 | |
Deferred
tax liabilities | |
| 2,819 | |
Total
liabilities assumed | |
| 20,308 | |
| |
| | |
Total
consideration paid and liabilities assumed | |
$ | 88,006 | |
| |
| | |
Allocation to acquired
assets: | |
| | |
Proved
oil and gas properties(1) | |
| 87,672 | |
Vehicles | |
| 165 | |
Deposit
account | |
| 169 | |
| |
| | |
Total
allocation to acquired assets | |
$ | 88,006 | |
(1) |
Included
in the above purchase price adjustments is settlement for oil in temporary storage at the lease in tank batteries. The Company does
not separately account for oil in temporary storage until the oil is sold and title transfers to the purchaser. Consistent with the
Company’s accounting policy and reporting of similar transactions this amount was recorded within Evaluated Properties on the
Company’s condensed consolidated balance sheet. |
Liberty
County, Texas Acquisition
On
May 3, 2022, the Company acquired certain operated oil and gas producing properties in Liberty County, Texas, adjacent to its existing
assets in the area, for $1.0 million in an all-cash transaction. The effective date of the transaction was April 1, 2022. The assets
include approximately 1,022 acres, which are 100% held by production, a gas pipeline and associated infrastructure. In addition, the
Company assumed suspense accounts of $0.2 million and asset retirement obligations of $0.5 million. The Company accounted for the acquisition
as an asset acquisition.
East
Texas Acquisition
On
July 27, 2022, the Company closed a purchase and sale agreement for the acquisition of properties from ETXENERGY, LLC (“ETXENERGY”).
The properties are located in Henderson and Anderson Counties, Texas (the “East Texas Assets”). The properties consist of
approximately 16,600 net acres, all of which are held by production and certain wells and gathering systems. The initial purchase price
for the East Texas Assets was $11.9 million in cash. The effective date of the acquisition of the East Texas Assets was June 1, 2022.
The Company accounted for the acquisition as an asset acquisition.
SUMMARY
OF AMOUNTS INCURRED FOR ASSETS ACQUIRED
| |
Amount | |
| |
(in thousands) | |
Amounts incurred: | |
| | |
Cash | |
$ | 11,875 | |
Purchase price adjustments | |
| (1,048 | ) |
Transaction
costs | |
| 63 | |
Total
consideration paid | |
| 10,890 | |
| |
| | |
Suspense accounts assumed | |
| 380 | |
Asset
retirement obligations assumed | |
| 1,689 | |
Total
liabilities assumed | |
| 2,069 | |
| |
| | |
Total
consideration paid and liabilities assumed | |
$ | 12,959 | |
| |
| | |
Allocation to acquired
assets: | |
| | |
Proved
oil and gas properties | |
$ | 12,959 | |
3.
REVENUE RECOGNITION
The
Company’s operated oil production is sold at the delivery point specified in the contract. The Company collects an agreed-upon
index price, net of pricing differentials. The purchaser takes custody, title and risk of loss of the oil at the delivery point; therefore,
control passes at the delivery point. The Company does not separately account for oil in temporary storage at the site of production
prior to its transfer to the purchaser. The Company recognizes revenue at the net price received when control transfers to the purchaser.
Natural gas and natural gas liquid (“NGL”) are sold at the lease location, which is generally when control of the natural
gas and NGL transfers to the purchaser, and revenue is recognized as the amount received from the purchaser.
The
Company does not disclose the values of unsatisfied performance obligations under its contracts with customers as it applies the practical
exemption in accordance with Accounting Standards Codification (ASC) 606. The exemption applies to variable consideration that is recognized
as control of the product is transferred to the customer. Since each unit of product represents a separate performance obligation, future
volumes are wholly unsatisfied, and disclosure of the transaction price allocated to the remaining performance obligations is not required.
The
Company reports operated revenue as the gross amount received from the purchasers before taking into account transportation costs.
Production taxes are reported separately, and transportation costs are included in lease operating expense in the accompanying
condensed consolidated statements of operations. The revenue and costs in the condensed consolidated statements of operations were
reported gross for the three months ended March 31, 2023 and 2022, as the gross amounts were known.
The
Company reports non-operated revenue as the Company’s net share received from the well operators. Production taxes are reported
separately, and transportation costs are included in lease operating expense in the accompanying unaudited condensed consolidated statements
of operations. The revenue and costs were reported gross for the three months ended March 31, 2023 and 2022, as the gross amounts were
known.
The
Company’s non-operated revenues are derived from its interest in the sales of oil and natural gas production. The sales of oil
and natural gas are made under contracts that operators of the wells have negotiated with third-party customers. The Company
receives payment from the sale of oil and natural gas production between one to three months after delivery. At the end of each
period when the performance obligation is satisfied, the variable consideration can be reasonably estimated and amounts due from
customers are accrued in oil and natural gas sales receivable in the condensed consolidated balance sheets. Variances between the
Company’s estimated revenue and actual payments are recorded in the month the payment is received; however, differences have
been, and are expected to be, insignificant. Accordingly, the variable consideration is not constrained. As a non-operator of its oil
and natural gas properties, the Company records its share of the revenues and expenses based upon the information provided by the
operators within the revenue statements.
The
Company’s oil and natural gas production is typically sold at delivery points to various purchasers under contract terms that are
common in the oil and natural gas industry. Regardless of the contract type, the terms of these contracts compensate the well operators
for the value of the oil and natural gas at specified prices, and then the well operators remit payment to the Company for its share
in the value of the oil and natural gas sold.
The
Company disaggregates revenues from its share of revenue from the sale of oil and natural gas and liquids by region. The Company’s
revenues in its Rockies, West Texas, South Texas, Gulf Coast and Mid- Continent regions for the three months ended March 31, 2023 and
2022, are presented in the following table:
SCHEDULE
OF DISAGGREGATED REVENUE
| |
2023 | | |
2022 | |
| |
Three
months ended March 31, | |
| |
2023 | | |
2022 | |
| |
(in thousands) | |
Revenue: | |
| | |
| |
Rockies | |
| | |
| |
Oil | |
$ | 2,381 | | |
$ | 3,391 | |
Natural
gas and liquids | |
| 132 | | |
| 193 | |
Total | |
| 2,513 | | |
| 3,584 | |
| |
| | | |
| | |
South
Texas | |
| | | |
| | |
Oil | |
| 1,132 | | |
| 1,636 | |
Natural
gas and liquids | |
| 88 | | |
| 139 | |
Total | |
| 1,220 | | |
| 1,775 | |
| |
| | | |
| | |
West
Texas | |
| | | |
| | |
Oil | |
| 890 | | |
| 1,428 | |
Natural
gas and liquids | |
| 62 | | |
| 62 | |
Total | |
| 952 | | |
| 1,490 | |
| |
| | | |
| | |
Gulf
Coast | |
| | | |
| | |
Oil | |
| 727 | | |
| 717 | |
Natural
gas and liquids | |
| 108 | | |
| 4 | |
Total | |
| 835 | | |
| 721 | |
| |
| | | |
| | |
Mid-Continent
| |
| | | |
| | |
Oil | |
| 1,965 | | |
| 759 | |
Natural
gas and liquids | |
| 787 | | |
| 543 | |
Total | |
| 2,752 | | |
| 1,302 | |
| |
| | | |
| | |
Combined
Total | |
$ | 8,272 | | |
$ | 8,872 | |
Significant
concentrations of credit risk
The
Company has exposure to credit risk in the event of non-payment of oil and natural gas receivables by purchasers of its operated oil
and natural gas properties and the joint interest operators of the Company’s non-operated oil and natural gas properties. The following
table presents the purchasers that accounted for 10% or more of the Company’s total oil and natural gas revenue for at least one
of the periods presented:
SCHEDULE
OF CONCENTRATION OF CREDIT RISK
| |
2023 | | |
2022 | |
Purchaser A | |
| 18 | % | |
| 25 | % |
Purchaser B | |
| 15 | % | |
| - | % |
Purchaser C | |
| 13 | % | |
| 15 | % |
Purchaser D | |
| 11 | % | |
| 16 | % |
Concentration risk percentage | |
| 11 | % | |
| 16 | % |
4.
LEASES
The
Company’s right-of-use assets and lease liabilities are recognized at their discounted present value under the following captions
in the condensed consolidated balance sheets at March 31, 2023 and December 31, 2022:
SCHEDULE
OF CONSOLIDATED BALANCE SHEET
| |
March
31, 2023 | | |
December
31, 2022 | |
| |
(in thousands) | |
Right of use asset balance | |
| | |
| |
Operating
lease | |
$ | 813 | | |
$ | 868 | |
Lease liability balance | |
| | | |
| | |
Short-term operating lease | |
$ | 174 | | |
$ | 189 | |
Long-term
operating lease | |
| 750 | | |
| 794 | |
Total operating leases | |
$ | 924 | | |
$ | 983 | |
The
Company recognizes lease expense on a straight-line basis excluding short-term and variable lease payments, which are recognized as incurred.
Short-term lease cost represents payments for office leases with original terms less than one year. Beginning in March 2020, the Company
subleased its Denver, Colorado office and recognized sublease income as a reduction of rent expense. The term of the sublease was through
the term of the Company’s Denver office lease, which terminated on January 31, 2023. Following are the amounts recognized as components
of rental expense for the three months ended March 31, 2023 and 2022:
SCHEDULE
OF LEASE COSTS
| |
2023 | | |
2022 | |
| |
Three
Months ended March 31, | |
| |
2023 | | |
2022 | |
| |
(in thousands) | |
Operating lease cost | |
$ | 65 | | |
$ | 31 | |
Short-term lease cost | |
| 269 | | |
| 2 | |
Sublease income | |
| - | | |
| (16 | ) |
Total lease costs | |
$ | 334 | | |
$ | 17 | |
The
Company’s Houston office operating lease does not contain implicit interest rates that can be readily determined; therefore,
the Company used the incremental borrowing rates in effect at the time the Company entered into the leases.
SCHEDULE
OF WEIGHTED AVERAGE LEASE
| |
As
of March 31, | |
| |
2023 | | |
2022 | |
| |
(in thousands) | |
Weighted average lease term (years) | |
| 4.7 | | |
| 0.9 | |
Weighted average discount rate | |
| 4.25 | % | |
| 9.26 | % |
Maturity
of operating lease liabilities with terms of one year or more as of March 31, 2023 are presented in the following table:
SCHEDULE
OF FUTURE MINIMUM LEASE PAYMENTS
| |
March
31, 2023 | |
| |
(in thousands) | |
2023 | |
$ | 156 | |
2024 | |
| 213 | |
2025 | |
| 218 | |
2026 | |
| 224 | |
2027 | |
| 210 | |
Total lease payments | |
$ | 1,021 | |
Less: imputed interest | |
| (97 | ) |
Total lease liability | |
$ | 924 | |
5.
OIL AND NATURAL GAS PRODUCTION ACTIVITIES
Divestitures
During
the three months ended March 31, 2023 and 2022, there were no divestitures of oil and gas properties.
Ceiling
Test and Impairment
The
reserves used in the ceiling test incorporate assumptions regarding pricing and discount rates over which management has no influence
in the determination of present value. In the calculation of the ceiling test as of March 31, 2023, the Company used $90.97 per barrel
for oil and $5.95 per one million British Thermal Units (MMbtu) for natural gas (as further adjusted for property, specific gravity,
quality, local markets and distance from markets) to compute the future cash flows of the Company’s producing properties. The discount
factor used was 10%.
For
the three months ended March 31, 2023, and 2022, the Company did not record ceiling test write downs of its oil and natural gas properties.
6.
DEBT
On
January 5, 2022, the Company entered into a five-year credit agreement (“Credit Agreement”) with Firstbank Southwest (“Firstbank”)
as administrative agent for one or more lenders (the “Lenders”), which provided for a revolving line of credit with an initial
borrowing base of $15 million, and a maximum credit amount of $100 million. Borrowings under the Credit Agreement are collateralized
by a first priority, perfected lien and security interests on substantially all assets of the Company (subject to permitted liens and
other customary exceptions). On July 26, 2022, the Company, in anticipation of the closing of the ETXENERGY East Texas acquisition entered
into a letter agreement with FirstBank whereby it increased the borrowing base under the Credit Agreement from $15 million to $20 million.
On July 27, 2022, in connection with the closing of the ETXENERGY Acquisition, the Company borrowed $10.7 million under the Credit Agreement.
Under the Credit Agreement, revolving loans may be borrowed, repaid and re-borrowed until January 5, 2026, when all outstanding amounts
must be repaid. Interest on the outstanding amounts under the Credit Agreement will accrue at an interest rate equal to (a) the greatest
of (i) the prime rate in effect on such day, and (b) the Federal Funds rate in effect on such day (as determined in the Credit Agreement)
plus 0.50%, and an applicable margin that ranges between 0.25% to 1.25% depending on utilization of the amount of the borrowing base
(the “Applicable Margin”). The weighted average interest rate on the Credit Agreement for the three months ended March 31,
2023 and 2022, was 8.41% and 4.25% per annum, respectively. The Company recognized interest expense inclusive of amortization of debt
issuance costs on the Credit Agreement for the three months ended March 31, 2023 and 2022 of $263 thousand and $46 thousand, respectively.
The
Credit Agreement contains various restrictive covenants and compliance requirements, which include, among other things: (i)
maintenance of certain financial ratios, as defined in the Credit Agreement tested quarterly, that limit the Company’s ratio
of total debt to EBITDAX (as defined in the Credit Agreement) to 3:1 and require its ratio of consolidated current assets to
consolidated current liabilities (as each is described in the Credit Agreement) to remain at 1:1 or higher; (ii) restrictions on
making restricted payments as defined in the Credit Agreement, including the payment of cash dividends and repurchases of equity
interests (subject to certain limited rights to make restricted payments as long as no event of default has occurred, or would
result from the restricted payment, certain financial ratios are met and the borrowing availability after giving pro forma effect to any borrowing to be made on the date of the restricted
payment is greater than, or equal to, 20% of the then existing borrowing base); (iii) limits on the incurrence of additional indebtedness;
(iv) a prohibition on the entry into commodity swap contracts exceeding a specified percentage of our expected production; and (v)
restrictions on the disposition of assets. As of March 31, 2023, the borrowing base was $20
million, and the Company was in compliance with all financial covenants related to the Credit Agreement.
A
total of $3.5 million was borrowed under the Credit Agreement immediately upon the entry into such Credit Agreement on January 5, 2022.
The $3.5 million was immediately used to repay $3.3 million of debt assumed as part of the acquisition of the Acquired Assets. The amount
outstanding on the Credit Agreement as of March 31, 2023, was $12.0 million.
7.
COMMODITY DERIVATIVES
The
Company’s results of operations and cash flows are affected by changes in market prices for crude oil and natural gas. To
manage a portion of its exposure to price volatility from producing crude oil and natural gas, the Company enters into commodity
derivative contracts to protect against price declines in future periods. The Company does not enter into derivative contracts for
speculative purposes. The Company has not elected to designate the derivative contracts as cash flow hedges; therefore, the
instruments do not qualify for hedge accounting. Accordingly, changes in the fair value of the derivative contracts are recorded in
the condensed consolidated statements of operations and are included in cash flows from operating activities in the condensed
consolidated statement of cash flows.
On
January 5, 2022, the Company and NextEra Energy Marketing LLC (“NextEra”) entered into an International Swap Dealers Association,
Inc. Master Agreement and Schedule (the “Master Agreement”), facilitating the Company to enter into derivative contracts
to manage the risk associated with its business relating to commodity prices. The Company’s obligations to NextEra under the Master
Agreement are secured by the collateral which secures the loans under the Credit Agreement on a pari passu and pro rata basis with the
principal of such loans. The structure of the derivative contacts may include swaps, caps, floors, collars, locks, forwards and options.
The
Company’s entry into and the obligations of the Company under the Master Agreement were required conditions to the January 2022
acquisition closing, pursuant to which the Company was required to assume and novate certain hedges which had a mark to market loss of approximately
$3.1 million as of the Closing Date. In addition, on January 12, 2022, the Company entered into additional NYMEX WTI crude oil commodity
derivative contracts with NextEra for 2022 and 2023 production. As of March 31, 2023, the Company had commodity derivative contracts
outstanding through the fourth quarter of 2023 as summarized in the tables below:
SCHEDULE
OF COMMODITY DERIVATIVE CONTRACTS
| |
Collars | | |
Fixed
Price Swaps | |
Commodity/ Index/ | |
Quantity
Crude
oil | | |
Weighted
Average Prices | | |
Quantity
Crude
oil | | |
Weighted Average
Swap | |
Maturity
Period | |
(Bbls)(1) | | |
Floors | | |
Ceilings | | |
(Bbls)(1) | | |
Price | |
| |
| | |
| | |
| | |
| | |
| |
NYMEX WTI | |
| | | |
| | | |
| | | |
| | | |
| | |
Crude
Oil 2023 Contracts: | |
| | | |
| | | |
| | | |
| | | |
| | |
Second quarter 2023 | |
| 53,500 | | |
$ | 60.00 | | |
$ | 81.04 | | |
| 6,000 | | |
$ | 59.02 | |
Third quarter 2023 | |
| 52,600 | | |
$ | 60.00 | | |
$ | 81.04 | | |
| - | | |
$ | - | |
Fourth quarter 2023 | |
| 51,200 | | |
$ | 60.00 | | |
$ | 81.04 | | |
| - | | |
$ | - | |
Total 2023 | |
| 157,300 | | |
$ | 60.00 | | |
$ | 81.04 | | |
| 6,000 | | |
$ | 59.02 | |
(1) |
“Bbl” refers to one stock tank
barrel, or 42 U.S. gallons liquid volume, used in this report in reference to crude oil or other liquid hydrocarbons. |
The
following table details the fair value of commodity derivative contracts recorded in the accompanying balance sheets by category:
SCHEDULE
OF FAIR VALUE OF COMMODITY DERIVATIVE CONTRACTS
| |
March
31, 2023 | | |
December
31, 2022 | |
| |
(in thousands) | |
Derivative liabilities: | |
| | | |
| | |
Current
liabilities | |
$ | 369 | | |
$ | 1,694 | |
Total
derivative liabilities | |
$ | 369 | | |
$ | 1,694 | |
As
of March 31, 2023, all commodity derivative contracts held by the Company were subject to master netting arrangements with its counterparty.
The terms of the Company’s derivative agreements provide for offsetting of amounts payable or receivable between it and the counterparty
for contracts that settle on the same date. The Company’s agreements also provide that in the event of an early termination, the
counterparty has the right to offset amounts owed or owing under that and any other agreement. The Company’s accounting policy
is to offset positions that settle on the same date with the same counterparty. See Note 13-Fair Value Measurements
for disclosure of the fair value of derivative assets and liabilities on a gross and net basis.
The
following table summarizes the commodity components of the derivative settlement gain (loss) as well as the components of the net derivative
loss line-item presentation in the accompanying condensed consolidated statement of operations:
SCHEDULE
OF DERIVATIVE SETTLEMENT GAIN LOSS
| |
2023 | | |
2022 | |
| |
Three
Months Ended March 31, | |
| |
2023 | | |
2022 | |
| |
(in thousands) | |
Derivative settlement gain (loss) | |
| | | |
| | |
Oil contracts | |
$ | (378 | ) | |
$ | (1,547 | ) |
Gas
contracts | |
| (28 | ) | |
| (97 | ) |
Total net derivative
settlement gain (loss) | |
$ | (406 | ) | |
$ | (1,644 | ) |
| |
| | | |
| | |
Total net derivative gain (loss) | |
| | | |
| $ | |
Oil contracts | |
$ | 859 | | |
| (6,296 | ) |
Gas
contracts | |
| 60 | | |
| (541 | ) |
Total net derivative
gain (loss) | |
$ | 919 | | |
$ | (6,837 | ) |
8.
COMMITMENTS AND CONTINGENCIES
Contingencies
The Company is subject to litigation and claims arising
in the ordinary course of business. The Company accrues for such items when a liability is both probable and the amount can be reasonably
estimated. In the opinion of management, the anticipated results of any pending litigation and claims are not expected to have a material
effect on the results of operations, the financial position, or the cash flows of the Company.
9.
SHAREHOLDERS’ EQUITY
At
March 31, 2023, the Company had 25,234,672 shares of common stock outstanding and 245,000,000 authorized. In addition, as of March 31,
2023, the Company had 5,000,000 authorized but unissued shares of preferred stock. On January 5, 2022, the Company issued 19,905,736
shares of common stock in connection with the acquisition of the Acquired Assets.
Stock
Options Plans
From
time to time, the Company may grant stock options under its incentive plan covering shares of common stock to employees of the Company.
Stock options, when exercised, are settled through the payment of the exercise price in exchange for new shares of stock underlying the
option. These awards typically expire ten years from the grant date.
For
the three months ended March 31, 2023 and 2022, there was no
compensation expense related to stock options. As of March 31, 2022, all stock options had vested. No
stock options were granted or exercised during the three months ended March 31, 2023 or 2022. Stock options to purchase 750
shares of common stock expired during the three months ended March 31, 2022. Presented below is information about stock options
outstanding and exercisable as of March 31, 2023, and December 31, 2022:
SCHEDULE
OF STOCK OPTIONS ACTIVITY
| |
March
31, 2023 | | |
December
31, 2022 | |
| |
Shares | | |
Price | | |
Shares | | |
Price | |
| |
| | | |
| | | |
| | | |
| | |
Stock options outstanding
and exercisable | |
| 28,122 | | |
$ | 54.03 | | |
| 28,122 | | |
$ | 54.03 | |
The
following table summarizes information for stock options outstanding and for stock options exercisable at March 31, 2023:
SCHEDULE
OF STOCK OPTIONS OUTSTANDING AND EXERCISABLE
Options
Outstanding | | |
Options
Exercisable | |
| | |
Exercise | | |
Weighted | | |
Remaining | | |
| | |
Weighted | |
Number
of | | |
Price
Range | | |
Average
Exercise | | |
Contractual
Term | | |
Number
of | | |
Average
Exercise | |
Shares | | |
Low | | |
High | | |
Price | | |
(years) | | |
Shares | | |
Price | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| 16,500 | | |
$ | 7.20 | | |
$ | 11.60 | | |
$ | 10.00 | | |
| 4.5 | | |
| 16,500 | | |
$ | 10.00 | |
| 10,622 | | |
| 90.00 | | |
| 124.80 | | |
| 106.20 | | |
| 1.1 | | |
| 10,622 | | |
| 106.20 | |
| 1,000 | | |
| 226.20 | | |
| 226.20 | | |
| 226.20 | | |
| 1.5 | | |
| 1,000 | | |
| 226.20 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
| 28,122 | | |
$ | 7.20 | | |
$ | 226.20 | | |
$ | 54.03 | | |
| 3.1 | | |
| 28,122 | | |
$ | 54.03 | |
Restricted
Stock
The
Company grants restricted stock under its incentive plan covering shares of common stock to employees and directors of the Company. In January 2023, 796,434 restricted stock awards were granted to employees
and directors from the 2021 Equity Incentive Plan. The
restricted stock awards are time-based awards and are amortized ratably over the requisite service period. Restricted stock vests ratably
on each anniversary following the grant date provided the grantee is employed on the vesting date. Forfeitures of restricted stock awards
are recognized as they occur. Restricted stock granted to employees, when vested, may be settled through the net issuance of shares,
reduced by the number of shares required to pay withholding taxes. Non-vested shares of restricted stock are not included in common shares
outstanding until vesting has occurred.
The
following table presents the changes in non-vested, time-based restricted stock awards to all employees and directors for the three months
ended March 31, 2023:
SCHEDULE
OF NON-VESTED TIME- BASED RESTRICTED STOCK AWARDS
| |
Shares | | |
Weighted-Avg.
Grant Date Fair Value per Share | |
| |
| |
Non-vested restricted stock as of December 31, 2022 | |
| 687,000 | | |
$ | 3.79 | |
Granted | |
| 796,434 | | |
$ | 2.30 | |
Vested | |
| (273,000 | ) | |
$ | 3.78 | |
Non-vested restricted stock as of March
31, 2023 | |
| 1,210,434 | | |
$ | 2.81 | |
For
the three months ended March 31, 2023 and 2022, the Company recognized $0.7 million and $1.5 million, respectively of stock compensation
expense related to restricted stock grants. Total compensation cost related to non-vested time-based awards and not yet recognized in
the Company’s condensed consolidated statements of operations as of March 31, 2023 was $2.6 million. This cost is expected to be
recognized over a weighted average period of 2.1 years.
10.
ASSET RETIREMENT OBLIGATIONS
The
Company has asset retirement obligations (“AROs”) associated with the future plugging and abandonment of proved properties.
Initially, the fair value of a liability for an ARO is recorded in the period in which the ARO is incurred with a corresponding increase
in the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depleted
over the life of the related asset. If the liability is settled for an amount other than the recorded amount, an adjustment to the full-cost
pool is recognized. The Company had no assets that are restricted for the purpose of settling AROs.
The
Company recorded $9.6 million of ARO related to the assets acquired in the January 5, 2022 acquisition, $0.5 million of ARO related to
the assets acquired in the May 3, 2022 acquisition of Liberty County, Texas assets and $1.7 million of ARO related to the assets acquired
in the July 27, 2022 acquisition. See Note 2- Acquisitions.
In
the fair value calculation for the ARO there are numerous assumptions and judgments, including the ultimate retirement cost, inflation
factors, credit-adjusted risk-free discount rates, timing of retirement and changes in legal, regulatory, environmental, and political
environments. To the extent future revisions to assumptions and judgments impact the present value of the existing ARO, a corresponding
adjustment is made to the oil and natural gas property balance.
The
following is a reconciliation of the changes in the Company’s liabilities for asset retirement obligations as of March 31, 2023
and December 31, 2022:
SCHEDULE
OF ASSET RETIREMENT OBLIGATION
| |
March
31, 2023 | | |
December
31, 2022 | |
| |
(in thousands) | |
Balance, beginning of year | |
$ | 15,442 | | |
$ | 1,461 | |
Acquired | |
| 11 | | |
| 11,811 | |
Cost and life revisions | |
| 41 | | |
| 1,825 | |
Plugged | |
| (11 | ) | |
| (407 | ) |
Sold | |
| - | | |
| (189 | ) |
Accretion | |
| 265 | | |
| 941 | |
Balance, end of period | |
$ | 15,748 | | |
$ | 15,442 | |
11.
INCOME TAXES
The
Company’s tax provision or benefit from income taxes for interim periods is determined using an estimate of its annual effective
tax rate, adjusted for discrete items, if any. Each quarter the Company updates its estimate of the annual effective tax rate and makes
a year-to-date adjustment to the provision. The Company’s effective tax rate was approximately 4% and 43% for the three months
ended March 31, 2023 and 2022, respectively. The primary difference in the Company’s effective tax rate and the statutory rate
for the three months ended March 31, 2023 related to the movement in the valuation allowance against the Company’s net deferred
tax assets.
The
Company’s income tax benefit for the three months ended March 31, 2022 includes a discrete income tax benefit of $2.4 million related
to the release of a portion of the Company’s previously established valuation allowance to offset deferred tax liabilities arising
from the January 5, 2022 transaction.
Deferred
taxes are recognized for the expected future tax consequences of temporary differences between the financial statement and tax basis
of assets, liabilities, net operating losses and tax credit carry-forwards. We review our deferred tax assets (“DTAs”) and
valuation allowance on a quarterly basis. As part of our review, we consider positive and negative evidence, including cumulative results
in recent years. The January 5, 2022 transaction triggered an Internal Revenue Code Section 382 ownership change, and therefore placed
additional limitations on the Company’s pre-transaction NOL and other tax attributes. As such, the Company is projecting that as
of December 31, 2023 it will not have sufficient DTAs available to offset the expected future taxable income that will be generated by
the realization of the Company’s deferred tax liabilities.
The
Company recognizes, measures, and discloses uncertain tax positions whereby tax positions must meet a “more-likely-than-not”
threshold to be recognized. During the three months ended March 31, 2023 and 2022, no adjustments were recognized for uncertain tax positions.
12.
LOSS PER SHARE
Basic
net loss per common share is calculated by dividing net loss attributable to common shareholders by the weighted-average number of common
shares outstanding for the respective period. Diluted net loss per common share is calculated by dividing adjusted net loss by the diluted
weighted average number of common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive
securities for this calculation consist of stock options and unvested shares of restricted common stock, which are measured using the treasury stock method. When the Company recognizes
a net loss, as was the case for the three months ended March 31, 2023 and 2022, all potentially dilutive shares are anti-dilutive and
are consequently excluded from the calculation of dilutive net loss per common share.
The
following table sets forth the calculation of basic and diluted net loss per share for the three months ended March 31, 2023 and 2022:
SCHEDULE
OF BASIC AND DILUTED NET LOSS PER SHARE
| |
| | | |
| | |
| |
Three
Months Ended March 31, | |
| |
2023 | | |
2022 | |
| |
(in thousands except per share
data) | |
Net loss
applicable to common shareholders | |
$ | (1,247 | ) | |
$ | (3,384 | ) |
| |
| | | |
| | |
Basic weighted-average common shares outstanding | |
| 25,179 | | |
| 23,717 | |
Dilutive effect of potentially
dilutive securities | |
| - | | |
| - | |
Diluted weighted-average
common shares outstanding | |
| 25,179 | | |
| 23,717 | |
| |
| | | |
| | |
Basic net loss per share | |
$ | (0.05 | ) | |
$ | (0.14 | ) |
Diluted net loss per share | |
$ | (0.05 | ) | |
$ | (0.14 | ) |
For
the three months ended March 31, 2023 and 2022, potentially dilutive securities excluded from the calculation of weighted average shares
because they were anti-dilutive are as follows:
SCHEDULE
OF ANTI-DILUTIVE WEIGHTED AVERAGE SHARES
| |
2023 | | |
2022 | |
| |
(in thousands) | |
Stock options | |
| 28 | | |
| 30 | |
Unvested shares of restricted stock | |
| 1,210 | | |
| 787 | |
Total | |
| 1,238 | | |
| 817 | |
13.
FAIR VALUE MEASUREMENTS
The
Company’s fair value measurements are estimated pursuant to a fair value hierarchy that requires us to maximize the use of observable
inputs and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the transparency
of inputs to the valuation of an asset or liability as of the measurement date, giving highest priority to quoted prices in active markets
(Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in
different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement in its entirety
determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement
in its entirety requires judgment, considering factors specific to the asset or liability, and may affect the valuation of the assets
and liabilities and their placement within the hierarchy level. The three levels of inputs that may be used to measure fair value are
defined as:
Level
1 - Quoted prices for identical assets and liabilities traded in active exchange markets.
Level
2 - Observable inputs other than Level 1 that are directly or indirectly observable for the asset or liability, including quoted
prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive
markets, or other observable inputs that can be corroborated by observable market data.
Level
3 - Unobservable inputs supported by little or no market activity for financial instruments whose value is determined using pricing models,
discounted cash flow methodologies, or similar techniques, as well as instruments for which the determination of fair value requires
significant management judgment or estimation.
The
Company has processes and controls in place to attempt to ensure that fair value is reasonably estimated. The Company performs due diligence
procedures over third-party pricing service providers in order to support their use in the valuation process. Where market information
is not available to support internal valuations, independent reviews of the valuations are performed, and any material exposures are
evaluated through a management review process.
While
the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies
or assumptions to determine the fair value of certain financial instruments could result in a different estimate of fair value at the
reporting date. The following is a description of the valuation methodologies used for complex financial instruments measured at fair
value:
Recurring
Fair Value Measurements
Commodity
Derivative Instruments
The
Company measures the fair value of commodity derivative contracts using an income valuation technique based on the contract price of
the underlying positions, crude oil and natural gas forward curves, discount rates, and Company or counterparty non-performance risk.
The fixed-price swaps and collar derivative contracts are included in Level 2. The fair value of commodity derivative contracts and their
presentation in our unaudited condensed consolidated balance sheet as of March 31, 2023 are presented below:
SCHEDULE
OF RECURRING MEASUREMENTS OF FAIR VALUE OF ASSETS AND LIABILITIES
| |
Quoted
Prices in Active Markets for Identical Assets (Level 1) | | |
Significant
Other Observable Inputs (Level 2) | | |
Significant
Unobservable Inputs (Level 3) | | |
Total
Fair Value | | |
Effect
of Netting | | |
Net
Fair Value Presented in the Unaudited Condensed Consolidated Balance Sheet | |
(in thousands) |
Assets | |
| | |
| | |
| | |
| | |
| | |
| |
Current: | |
| | |
| | |
| | |
| | |
| | |
| |
Commodity derivatives | |
$ | - | | |
$ | 325 | | |
$ | - | | |
$ | 325 | | |
$ | (325 | ) | |
$ | - | |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Liabilities | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Current: | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Commodity
derivatives | |
$ | - | | |
$ | (694 | ) | |
$ | - | | |
$ | (694 | ) | |
$ | 325 | | |
$ | (369 | ) |
| |
| | | |
| | | |
| | | |
| | | |
| | | |
| | |
Net derivative instruments | |
$ | - | | |
$ | (369 | ) | |
$ | - | | |
$ | (369 | ) | |
$ | - | | |
$ | (369 | ) |
Marketable
Equity Securities
We
measure the fair value of marketable equity securities based on quoted market prices obtained from independent pricing services. The
Company has an investment in the marketable equity securities of Anfield Energy (“Anfield”), which it acquired as consideration
for sales of certain mining operations. Anfield is traded in an active market under the trading symbol AEC:TSXV and has been classified
as Level 1.
SCHEDULE
OF INVESTMENT IN THE MARKETABLE EQUITY SECURITIES
| |
March 31, | | |
December 31, | |
| |
2023 | | |
2022 | |
Current assets: | |
| | | |
| | |
Marketable equity securities | |
| | | |
| | |
Number of shares owned | |
| 2,421,180 | | |
| 2,421,180 | |
Quoted market price | |
$ | 0.04430 | | |
$ | 0.04429 | |
| |
| | | |
| | |
Fair
value of marketable equity securities | |
$ | 107,258 | | |
$ | 107,234 | |
Nonrecurring
Fair Value Measurements
Asset
Retirement Obligations
The
Company measures the fair value of asset retirement obligations as of the date a well is acquired, the date a well begins drilling, or
the date the Company revises its ARO assumptions. The Company’s estimated asset retirement obligation is based on historical experience
in plugging and abandoning wells, estimated economic lives, estimated plugging and abandonment costs and federal and state regulatory
requirements, all unobservable inputs, and therefore, are designated as Level 3 within the valuation hierarchy. The liability is discounted
using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised. The credit adjusted risk-free rate
used to discount the Company’s plugging and abandonment liabilities range from 7.30% to 9.75%. See Note 10-Asset Retirement
Obligations.
Other
Assets and Liabilities
The
Company evaluates the fair value on a non-recurring basis of properties acquired in asset acquisitions using inputs that are not observable
in the market and are therefore designated as Level 3 inputs within the fair value hierarchy. The Company evaluated the fair value of
its January 2022 asset acquisition based on discounted future cash flows using estimated production at estimated prices based on NYMEX
strip pricing adjusted for differentials, operating costs, production taxes and development costs, all discounted at 10%. This evaluation
resulted in an estimate of fair value of $87.7 million. The Company has also valued asset acquisitions using a multiple of expected cash
flows based on comparable transactions. For the asset acquisition of East Texas assets that was completed on July 27, 2022, the Company
used a cash flow multiple of approximately 1.75 times estimated cash flows of $7.3 million.
The
Company evaluates the fair value on a non-recurring basis of its 13.84-acre land parcel in Riverton, Wyoming , which is currently listed for sale and classified as held for sale, when
circumstances indicate that the value has been impaired. At March 31 2023, the Company estimated the fair value of its real estate
assets based on a market approach with comparison to recent comparable sales, all Level 3 inputs within the fair value
hierarchy.
Credit
facility
The
Company’s credit facility approximates fair value because the interest rate is variable and reflective of market rates.
The
carrying value of financial instruments included in current assets and current liabilities approximate fair value due to the short-term
nature of those instruments.
14.
OTHER CURRENT ASSETS AND ACCOUNTS PAYABLE AND ACCRUED LIABILITIES
Other
Current Assets
The
following table presents the components of other current assets as of the dates indicated:
SCHEDULE
OF OTHER CURRENT ASSETS
| |
March
31, 2023 | | |
December
31, 2022 | |
| |
(in thousands) | |
Prepaid expense | |
$ | 747 | | |
$ | 138 | |
Joint interest billings receivable | |
| 325 | | |
| 332 | |
Income tax receivable | |
| 50 | | |
| 50 | |
Other | |
| 38 | | |
| 38 | |
| |
| | | |
| | |
Total
other current assets | |
$ | 1,160 | | |
$ | 558 | |
Accounts
Payable and Accrued Liabilities.
The
following table presents the components of accounts payable and accrued liabilities as of the dates indicated:
SCHEDULE
OF ACCOUNTS PAYABLE AND ACCRUED LIABILITIES
| |
March
31, 2023 | | |
December
31, 2022 | |
| |
(in thousands) | |
Accounts payable | |
$ | 2,212 | | |
$ | 2,566 | |
Operating expense accruals | |
| 1,055 | | |
| 1,378 | |
Revenue payables | |
| 3,582 | | |
| 3,503 | |
Production taxes payable | |
| 186 | | |
| 319 | |
Insurance premium financing | |
| 597 | | |
| 54 | |
Other | |
| 9 | | |
| 12 | |
| |
| | | |
| | |
Total accounts payable
and accrued expenses | |
$ | 7,641 | | |
$ | 7,832 | |
15.
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
SCHEDULE
OF SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
| |
| | | |
| | |
| |
Three
Months Ended March 31, | |
| |
2023 | | |
2022 | |
| |
(in thousands) | |
Cash paid for interest | |
$ | (268 | ) | |
$ | (36 | ) |
| |
| | | |
| | |
Investing activities: | |
| | | |
| | |
Change in capital expenditure accruals | |
$ | 18 | | |
$ | 166 | |
Change in accrual for acquisition costs | |
| - | | |
| (546 | ) |
Common stock issued for acquisition of properties | |
| - | | |
| 64,694 | |
Assumption of commodity derivative liability
in acquisition of properties | |
| - | | |
| 3,152 | |
Assumption of debt in acquisition of properties | |
| - | | |
| 3,347 | |
Assumption of suspense accounts in acquisition
of properties | |
| - | | |
| 1,276 | |
Addition of operating lease liability and right
of use asset | |
| - | | |
| - | |
Asset retirement obligations | |
| 43 | | |
| 9,614 | |
Financing activities: | |
| | | |
| | |
Financing of insurance premiums with note payable | |
$ | 654 | | |
$ | 588 | |
16.
SUBSEQUENT EVENTS
On
April 26, 2023, the Board of Directors of the Company authorized and approved a share repurchase program for up to $5.0 million of the
currently outstanding shares of the Company’s common stock. Subject to any future extensions, the repurchase program is scheduled
to expire on June 30, 2024, when a maximum of $5.0 million of the Company’s common stock has been repurchased, or when the program
is discontinued by the Company.
Under
the stock repurchase program, shares may be repurchased from time to time in the open market or through negotiated transactions at prevailing
market rates, or by other means in accordance with federal securities laws. Repurchases will be made at management’s discretion
at prices management considers to be attractive and in the best interests of both the Company and its stockholders, subject to the availability
of stock, general market conditions, the trading price of the stock, alternative uses for capital, and the Company’s financial
performance. The repurchase program will be funded using the Company’s working capital.
On May 8, 2023, the Company’s
Board of Directors approved a quarterly dividend of $0.0225 per share of common stock outstanding. The dividend will be paid on May 30,
2023, to stockholders of record as of the close of business on May 19, 2023.