US ENERGY CORP - Quarter Report: 2020 June (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

Commission File Number 000-06814

U.S. ENERGY CORP.

(Exact Name of Registrant as Specified in its Charter)

Not Applicable

(Former name, former address and former fiscal year, if changed since last report)

Securities registered pursuant to Section 12(b) of the Act:

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. YES [X] NO [  ]

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 and post such files). YES [X] NO [  ]

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.

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 is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES [  ] NO [X]

The registrant had 1,399,754 shares of its common stock, par value $0.01, outstanding as of August 7, 2020.

TABLE OF CONTENTS

Part I. FINANCIAL INFORMATION

Item 1. Financial Statements

U.S. ENERGY CORP. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except share and per share amounts)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

U.S. ENERGY CORP. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except share and per share amounts)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

U.S. ENERGY CORP. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES

IN SHAREHOLDERS’ EQUITY

FOR THE SIX MONTHS ENDED JUNE 30, 2020 AND 2019

(in thousands, except share amounts)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

U.S. ENERGY CORP. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE SIX MONTHS ENDED JUNE 30, 2020 AND 2019

(in thousands)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

U.S. ENERGY CORP. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION, OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES

Organization and Operations

U.S. Energy Corp. (collectively with its wholly owned subsidiaries, is referred to as the “Company” in these Notes to Unaudited Condensed Consolidated Financial Statements) was incorporated in the State of Wyoming on January 26, 1966. The Company’s principal business activities are focused in 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 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, 2019. Our financial condition as of June 30, 2020, and operating results for the three and six months ended June 30, 2020, 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, 2020.

Reverse Stock Split

On January 6, 2020, the Company completed a one-for-ten reverse stock split (the “Reverse Stock Split”) with respect to the Company’s common stock. For purposes of presentation, the unaudited condensed consolidated financial statements and footnotes have been adjusted for the number of post-split shares as if the split had occurred at the beginning of earliest period presented.

Liquidity and Resources

As of June 30, 2020, the Company had cash of $0.8 million, working capital of $1.3 million, which includes $725 thousand related to our real estate in Riverton, Wyoming classified as held for sale, and an accumulated deficit of $131.5 million. The Company’s liquidity is affected to a large degree by commodity prices, which have declined significantly since early March 2020, and although prices have increased recently, they remained historically low for much of the three-month period ended June 30, 2020. Currently, the Company does not have any commodity derivative contracts in place to protect it in the event of a further downturn in commodity prices. Management believes that its existing cash, capital resources, which include expected proceeds from the sale of its Riverton, Wyoming building and its investment in marketable securities have alleviated any substantial doubt regarding its ability to continue as a going concern. The Company expects that it will be able to fund operations for the next twelve months.

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 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; valuation of warrant instruments; valuation of assets acquired and liabilities assumed in business combinations and the cost 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.

Principles of Consolidation

The accompanying financial statements include the accounts of U.S. Energy Corp. and its wholly owned subsidiaries Energy One LLC (“Energy One”) and New Horizon Resources LLC (“New Horizon”). All inter-company balances and transactions have been eliminated in consolidation.

Recently Adopted Accounting Pronouncements

Fair Value Measurements. In August 2018, the FASB issued ASU No. 2018-13, Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurements. The ASU amends the disclosure requirements in Topic 820, Fair Value Measurements. The amendments in this ASU are effective for all entities for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. As a result of the Company’s adoption of this ASU on January 1, 2020, the fair value measurement disclosures for the warrants, which are the Company’s only Level 3 fair value measurement changed. The Company removed the disclosure of the processes for measuring the warrants and added quantitative information of the significant unobservable inputs used to develop the valuation of the warrants.

2. ACQUISITION OF NEW HORIZON RESOURCES

On March 1, 2020, The Company acquired all the issued and outstanding equity interests of New Horizon. Its assets include acreage and operated producing properties in North Dakota (the “Properties”). The consideration paid at closing consisted of 59,498 shares of the Company’s common stock, $150,000 in cash and the assumption of certain liabilities (the “Acquisition”). The Acquisition gives the Company operated properties in its core area of operations. The Properties consist of nine gross wells (five net wells), and approximately 1,300 net acres located primarily in McKenzie and Divide Counties, North Dakota, which are 100% held by production and average a 63% working interest.

For the six months ended June 30, 2020, the Company recorded revenues of approximately $33 thousand and lease operating expenses of approximately $69 thousand related to the New Horizon properties. Assuming that the acquisition of the New Horizon properties had occurred on January 1, 2019, the Company would have recorded revenues of $65 thousand and expenses of $91 thousand for the six months ended June 30, 2020, and revenues of $111 thousand and expenses of $49 thousand for the six months ended June 30, 2019. These results are not indicative of the results that would have occurred had the Company completed the acquisition on the date indicated, or that would be attained in the future. Subsequent to the closing of the Acquisition the Company repaid the outstanding balance on the credit facility and the credit facility was closed.

3. REAL ESTATE HELD FOR SALE

The Company owns a 14-acre tract in Riverton, Wyoming with a two-story, 30,400 square foot office building. The building served as the Company’s corporate headquarters until 2015 and is currently being leased to government agencies and other non-affiliated companies. In 2020 the Company made the decision to sell the land and building and began a process to determine the price at which it would list the property for sale. The process included obtaining an appraisal, analyzing operating statements for the building, reviewing capitalization rates and consulting a large national commercial real estate company. The Company determined that the realizable value of the building was in the range of $700 thousand to $900 thousand. A special committee of the board of directors was formed to evaluate the sales process and is exploring all available options to sell the land and building and will ultimately recommend any action to the Board of Directors regarding any potential sale. Following are the pre-impairment carrying amounts of the land and building at June 30, 2020, the estimated net proceeds, and a calculation of the loss recognized as a component of other income and expense in the condensed consolidated statement of operations.

4. REVENUE RECOGNITION

The Company’s revenues are derived from its interest in the sales of oil and natural gas production. Prior to the acquisition of New Horizon, which was completed on March 1, 2020, all of the sales of oil and natural gas were made under contracts that third-party operators of oil and natural gas wells have negotiated with 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 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 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 does not disclose the values of unsatisfied performance obligations under its contracts with customers as it applies the practical exemption in accordance with 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’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.

Generally, the Company reports revenue as the gross amount received from the well operators before taking into account production taxes and 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 revenues and costs in the condensed consolidated financial statements were reported gross for the three and six months ended June 30, 2020, as the gross amounts were known.

The following table presents our disaggregated revenue by major source and geographic area for the three and six months ended June 30, 2020 and 2019.

Significant concentrations of credit risk

The Company has exposure to credit risk in the event of nonpayment by joint interest operators and purchasers of the Company’s oil and natural gas properties. During the six-month periods ended June 30, 2020 and 2019, the joint interest operators that accounted for 10% or more of the Company’s total oil and natural gas revenue for at least one of the periods presented are as follows:

5. LEASES

On January 1, 2019, the Company adopted ASC 842 using the modified retrospective approach and recorded a $228 thousand right-of-use asset and a $252 thousand lease liability representing the present value of minimum payment obligations associated with the Company’s Denver office operating lease, which has non-cancellable terms in excess of one year. The Company does not have any financing leases. The Company has elected the following practical expedients available under ASC 842: (i) excluding from the condensed consolidated balance sheet leases with terms that are less than one year, (ii) for agreements that contain both lease and non-lease components, combining these components together and accounting for them as a single lease, (iii) the package of practical expedients, which allows the Company to avoid reassessing contracts that commenced prior to adoption that were properly evaluated under legacy GAAP, and (iv) the policy election that eliminates the need for adjusting prior period comparable financial statements prepared under legacy lease accounting guidance. As such, there was no required cumulative effect adjustment to accumulated deficit at January 1, 2019.

During the three and six months ended June 30, 2020 and 2019, the Company did not acquire any right-of-use assets or incur any lease liabilities. The Company’s right-of-use assets and lease liabilities are recognized at their discounted present value under the following captions in the unaudited condensed consolidated balance sheet at June 30, 2020 and December 31, 2019:

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 costs represent payments for our Houston office lease, which has a lease term of one year. Beginning in March 2020, the Company subleased its Denver office and recognized sublease income.

The Company’s Denver office operating lease does not contain an implicit interest rate that can be readily determined. Therefore, the Company used the incremental borrowing rate of 8.75% as established under the Company’s prior credit facility as the discount rate.

The future minimum lease commitments as of June 30, 2020 are presented in the table below. Such commitments are reflected at undiscounted values and are reconciled to the discounted present value on the unaudited condensed consolidated balance sheet as follows:

The Company owns a 14-acre tract in Riverton, Wyoming with a two-story, 30,400 square foot office building, which served as the Company’s corporate headquarters until it relocated to Denver, Colorado in 2015. Currently, the building’s eight office suites are rented to non-affiliates and government agencies under operating leases with varying terms from month-to-month to twelve years. The building is included in real estate held for sale on our condensed consolidated balance sheet. The Company recognized a loss on real estate held for sale related to the building and land during the three months ended June 30, 2020 of $651 thousand. The building will not be depreciated while it is held for sale. The net capitalized cost of the building and the land subject to operating leases at June 30, 2020 and December 31, 2019 is as follows:

The future lease maturities of the Company’s operating leases as of June 30, 2020 are presented in the table below. Such maturities are reflected at undiscounted values to be received on an annual basis.

The Company recognized the following loss on rental property related to its Riverton, Wyoming office building for the three and six months ended June 30, 2020 and 2019:

6. OIL AND NATURAL GAS PRODUCTION ACTIVITIES

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 June 30, 2020, the Company used $47.17 per barrel for oil and $2.07 per 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%.

The Company recorded a $1.8 million ceiling test write-down of its oil and gas properties during the three-month period ended June 30, 2020 due to a reduction in the value of proved oil and natural gas reserves primarily as a result of a decrease in crude oil prices and the performance of a South Texas well drilled in the prior year. In addition, the Company evaluated its unevaluated property at June 30, 2020 and recorded a reclassification to the depletable base of the full cost pool of $2.1 million related to a reduction in value of certain of its acreage.

7. DEBT

On December 27, 2017, the Company entered into an exchange agreement (“Exchange Agreement”) by and among U.S. Energy Corp., its wholly owned subsidiary Energy One LLC (“Energy One”) and APEG Energy II, L.P. (“APEG II”), pursuant to which, on the terms and subject to the conditions of the Exchange Agreement, APEG II exchanged $4.5 million of outstanding borrowings under the Company’s credit facility for 581,927 newly-issued shares of common stock of the Company, par value $0.01 per share, with an exchange price of $7.67, which represented a 1.3% premium over the 30-day volume weighted average price of the Company’s common stock on September 20, 2017 (the “Exchange Shares”). Accrued, unpaid interest on the credit facility held by APEG II was paid in cash at the closing of the transaction. At June 30, 2020, APEG II held approximately 42% of the Company’s outstanding common stock.

The credit facility was fully repaid on March 1, 2019 and on July 30, 2019, matured and was terminated. Borrowings under the credit facility were secured by Energy One’s oil and natural gas producing properties. Interest expense for the six months ended June 30, 2019 was $20 thousand, including the amortization of debt issuance costs of $7 thousand. The weighted average interest rate on the credit facility was 8.75% for the period until maturity in 2019.

8. WRITE-OFF OF DEPOSIT

In December 2017, the Company entered into a Letter of Intent (“LOI”) with Clean Energy Technology Association, Inc. (“CETA”) to purchase an option to acquire 50 shares of CETA, or lease certain oil and natural gas properties inside an area of mutual interest. The Company made a $250,000 option payment, which was refundable in the event that the Company and CETA were unable to complete the transaction by August 1, 2018. In 2018, the Company paid an additional $124,000 to CETA. In September 2019, the Company issued CETA a demand letter requesting return of the amounts deposited. As of June 30, 2020, the Company has received four payments from CETA totaling $225,000. While the Company is pursuing collection of $75,000 of the remaining deposit, the Company has established an allowance of the amount due from CETA at June 30, 2020, due to the uncertainty of collection. See Note 9-Commitments, Contingencies and Related-Party Transactions.

9. COMMITMENTS, CONTINGENCIES AND RELATED-PARTY TRANSACTIONS

Litigation

At June 30, 2020, APEG II and its general partner, APEG Energy II, GP (together with APEG II, “APEG”) were involved in litigation with the Company and its former Chief Executive Officer, David Veltri, as described below. As of June 30, 2020, APEG II held approximately 42% of the Company’s outstanding common stock and was the secured lender, prior to maturity on July 30, 2019 under the Company’s credit facility.

APEG II Litigation

On February 14, 2019, the Company’s board of directors (the Board”) (only one member of which remained on the Board following the Company’s 2019 Annual Meeting of Shareholders held on December 10, 2019) received a letter from APEG II urging the Company to establish a seven-person, independent board of directors, establish a corporate business plan and reduce its corporate general and administrative expenses. APEG II is the Company’s largest shareholder, owning approximately 42% of its outstanding common stock, and, as of December 31, 2018, was the secured lender under its credit facility, which the Company repaid in full as discussed below.

On February 25, 2019, APEG II provided an access termination notice to the Company’s bank under its collateral documents, which resulted in all of the funds held in the collateral accounts, which totaled approximately $1.8 million, being wired to APEG II on March 1, 2019. On March 1, 2019, David Veltri, the Company’s former Chief Executive Officer and President, filed a lawsuit against APEG II in the Company’s name (the “Texas Litigation”) in the District Court of Harris County Texas, 190^th Judicial District (the “Texas State Court”). The Texas State Court granted the motion for a temporary restraining order (“TRO”) and ordered APEG to return immediately the approximate $1.8 million in cash previously wired to APEG II.

On March 4, 2019, APEG II filed an emergency motion with the U.S. District Court for the Southern District of Texas (the “Texas Federal Court”) in order to remove the Texas Litigation from the Texas State Court to the Texas Federal Court and to stay or modify the TRO. Following a hearing on March 4, 2019, the Texas Federal Court vacated the TRO and the Court ordered APEG to return the Company’s funds, less the outstanding balance due to APEG II under the credit facility of approximately $937 thousand, resulting in the Company receiving approximately $850 thousand.

On February 25, 2019, the Company’s Board held a meeting at which it voted to terminate Mr. Veltri for cause as Chief Executive Officer and President as a result of using Company funds outside of his authority and other reasons. Mr. Veltri, along with John Hoffman, a former Board member, called into question whether or not such action was properly taken at the Board meeting. On March 8, 2019, the Company’s Audit Committee intervened in the Texas Litigation by filing an emergency motion (the “AC Motion”). The AC Motion requested that the Texas Federal Court order that all of the Company’s funds and matters be placed under the control of its Chief Financial Officer and that control of these functions be removed from its former Chief Executive Officer, who had been terminated by the Board on February 25, 2019.

On March 12, 2019, the Texas Federal Court granted the AC Motion, ordering that any disbursement made by the Company must be approved in writing by the Audit Committee in advance. Additionally, the Texas Federal Court ordered that the Company’s Chief Financial Officer must be appointed as the sole signatory on all of the Company’s bank accounts.

On July 30, 2020, the Company, filed a Notice of Voluntary Dismissal of its lawsuit against Mr. Veltri. The Company expects that all matters relating to the Texas Litigation will be dismissed in August 2020.

Litigation with Former Chief Executive Officer

In connection with the above described litigation with APEG II, APEG II then initiated a second lawsuit on March 18, 2019 as a shareholder derivative action in Colorado against Mr. Veltri, as a result of his refusal to recognize the Board’s decision to terminate him for cause (the “Colorado Litigation”). The Company was named as a nominal defendant in the Colorado Litigation. The APEG II complaint in the Colorado Litigation alleged that Mr. Veltri’s employment was terminated by the Board and sought an injunction and temporary restraining order against Mr. Veltri to prevent him from continuing to act as the Company’s Chief Executive Officer, President and Chairman.

On April 30, 2019, the Audit Committee took over the control of the defense of the Company, prosecution of its claims against APEG II, and filed third-party claims on behalf of the Company against Mr. Veltri and Mr. Hoffman, at the time a director of the Company, asserting that Mr. Veltri was responsible for any damages that APEG II claims, including attorneys’ fees, and that Mr. Veltri and Mr. Hoffman should be removed from the Board. On May 22, 2019, the Company and APEG II entered into a settlement agreement with Mr. Hoffman, pursuant to which Mr. Hoffman agreed to resign from the Board and committees thereof, and the Company agreed to pay up to $50,000 of his legal fees incurred. Further, the Company released Mr. Hoffman from any claims related to the Texas Litigation, APEG II released the Company from any claims that may have been caused by Mr. Hoffman, and Mr. Hoffman released the Company from any and all claims he may have had against the Company and its Board.

In the Colorado Litigation, the United States District Court for the District of Colorado (“the Colorado Federal Court”) granted interim preliminary injunctive relief to APEG II against Mr. Veltri, holding that Mr. Veltri, without authorization, continued to hold himself out to be, and continued to act as, the Company’s President and Chief Executive Officer. Pursuant to the Order, Mr. Veltri was preliminarily enjoined from acting as, or holding himself out to be, the Company’s President and/or Chief Executive Officer, pending a trial on the merits. Ryan Smith, the Company’s Chief Financial Officer at the time, was appointed temporary custodian of the Company with the charge to act as the Company’s Interim Chief Executive Officer.

On May 30, 2019, the Colorado Federal Court issued a subsequent order (the “Second Order”), appointing C. Randel Lewis as custodian of the Company pursuant to the Wyoming Business Corporation Act and to take over for Mr. Smith in acting as the Company’s Interim Chief Executive Officer and to serve on the Board as Chairman. The Second Order noted that the primary purpose of having Mr. Lewis serve as custodian was to resolve the Board deadlock regarding Mr. Veltri’s termination. Pursuant to the Second Order, Mr. Lewis, as custodian, was ordered to act in place of the Board to appoint one independent director to replace Mr. Hoffman. On June 13, 2019, Mr. Lewis appointed Catherine J. Boggs to serve as an independent director until the 2019 annual meeting of the Company’s shareholders, which was held on December 10, 2019. Following such annual meeting, the Board appointed Ryan Smith to serve as the Company’s Chief Executive Officer, replacing Mr. Lewis in that role. Following the annual meeting, the Colorado Federal Court also discharged Mr. Lewis from serving as custodian, Interim Chief Executive Officer and as a member of the Board.

On May 20, 2020, the Colorado Litigation was dismissed.

10. PREFERRED STOCK

The Company’s articles of incorporation authorize the issuance of up to 100,000 shares of preferred stock, $0.01 par value. Shares of preferred stock may be issued with such dividend, liquidation, voting and conversion features as may be determined by the Board without shareholder approval. The Company is authorized to issue 50,000 shares of Series P preferred stock in connection with a shareholder rights plan that expired in 2011.

On February 12, 2016, the Company issued 50,000 shares of newly designated Series A Convertible Preferred Stock (the “Preferred Stock”) to Mt. Emmons Mining Company (“MEM”), a subsidiary of Freeport McMoRan, pursuant to that certain Series A Convertible Preferred Stock Purchase Agreement (the “Series A Purchase Agreement”). The Preferred Stock was issued in connection with the disposition of the Company’s mining segment, whereby MEM acquired the property and replaced the Company as permittee and operator of a water treatment plant (the “Acquisition Agreement”). The Preferred Stock was issued at $40 per share for an aggregate $2 million. The Preferred Stock liquidation preference, initially $2 million, increases by quarterly dividends of 12.25% per annum (the “Adjusted Liquidation Preference”). At the option of the holder, each share of Preferred Stock may initially be converted into 1.33 shares of the Company’s $0.01 par value common stock (the “Conversion Rate”) for an aggregate of 66,667 shares. This Conversion Rate reflects the effect of the Reverse Stock Split. The Conversion Rate is subject to anti-dilution adjustments for stock splits, stock dividends and certain reorganization events and to price-based anti-dilution protections. At June 30, 2020 and December 31, 2019, after taking into account the effect of the Reverse Stock Split, the aggregate number of shares of common stock issuable upon conversion is 79,334 shares, which is the maximum number of shares issuable upon conversion.

The Preferred Stock is senior to other classes or series of shares of the Company with respect to dividend rights and rights upon liquidation. No dividend or distribution will be declared or paid on junior stock, including the Company’s common stock, (1) unless approved by the holders of Preferred Stock and (2) unless and until a like dividend has been declared and paid on the Preferred Stock on an as-converted basis. The Preferred Stock does not vote with the Company’s common stock on an as-converted basis on matters put before the Company’s shareholders. However, the holders of the Preferred Stock have the right to approve specified matters as set forth in the certificate of designation and have the right to require the Company to repurchase the Preferred Stock in the event of a change of control, which has not been triggered as of June 30, 2020. Concurrent with entry into the Acquisition Agreement and the Series A Purchase Agreement, the Company and MEM entered into an Investor Rights Agreement, which provides MEM rights to certain information and Board observer rights. MEM has agreed that it, along with its affiliates, will not acquire more than 16.86% of the Company’s issued and outstanding shares of common stock. In addition, MEM has the right to demand registration under the Securities Act of 1933, as amended, of the shares of common stock issuable upon conversion of the Preferred Stock

11. SHAREHOLDERS’ EQUITY

Warrants

In December 2016, the Company completed a registered direct offering of 100,000 shares of common stock at a net gross price of $15.00 per share. Concurrently, the investors received warrants to purchase 100,000 shares of common stock of the Company at an exercise price of $20.05 per share, subject to adjustment, for a period of five years from the final closing date of June 21, 2017. The total net proceeds received by the Company were approximately $1.32 million. The fair value of the warrants upon issuance was $1.24 million, with the remaining $0.08 million being attributed to common stock. The warrants have been classified as liabilities due to features in the warrant agreement that give the warrant holder an option to require the Company to redeem the warrant at a calculated fair value in the event of a “Fundamental Transaction,” as defined in the warrant agreement. The fair value of the warrants was $193 thousand and $73 thousand at June 30, 2020 and December 31, 2019, respectively

As a result of common stock issuances made during the year ended December 31, 2018, the warrant exercise price was reduced from $20.50 to $11.30 per share pursuant to the original warrant agreement.

Stock Options

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.

Total stock-based compensation expense related to stock options was $0 and $26 thousand for the six months ended June 30, 2020 and 2019, respectively. As of June 30, 2020, all stock options had vested. During the six months ended June 30, 2020 and 2019, no stock options were granted, exercised, or forfeited. During the six months ended June 30, 2020 stock options for 166 shares expired. Presented below is information about stock options outstanding and exercisable as of June 30, 2020 and December 31, 2019. All shares and prices per share have been adjusted for the Reverse Stock Split.

The following table summarizes information for stock options outstanding and for stock options exercisable at June 30, 2020:

In January 2020, the Company granted 48,000 restricted shares to the Company’s Chief Executive Officer, of which 24,000 shares vest after one year and 24,000 vest after two years. In addition, the Company granted a total of 28,000 restricted shares to members of the Board, which vest on January 28, 2021. For the six months ended June 30, 2020, the Company recognized $106 thousand in stock compensation expense related to these restricted stock grants. At June 30, 2020, the unrecognized expense related to the restricted stock grants was $266 thousand.

12. 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.

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 June 30, 2020 and December 31, 2019:

13. INCOME TAXES

The Company estimated the applicable effective tax rate expected for the full fiscal year. The Company’s effective tax rate used to estimate income taxes on a current year-to-date basis is 0% for both the three and six months ended June 30, 2020 and 2019.

In December 2017, the Company paid down debt through the issuance of common stock. This issuance represented a 49.3% ownership change in the Company. See Note 7-Debt. This change in ownership, combined with other equity events, triggered loss limitations under Internal Revenue Code Section 382. As a result, the Company wrote-off a total of $32.2 million of gross deferred tax assets through December 31, 2018. Since the Company maintains a valuation allowance against these tax assets, there was no impact to the condensed consolidated statements of operations.

Deferred tax assets (“DTAs”) are recognized for the expected future tax consequences of temporary differences between the financial reporting and tax basis of assets and liabilities and for operating losses and tax credit carryforwards. We review our 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. Consistent with the position at December 31, 2019, the Company maintains a full valuation allowance recorded against all DTAs. The Company, therefore, had no recorded DTAs as of June 30, 2020. We anticipate that we will continue to record a valuation allowance against our DTAs in all jurisdictions until such time as we are able to determine that it is “more-likely-than-not” that those DTAs will be realized.

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 and six months ended June 30, 2020 and 2019, no adjustments were recognized for uncertain tax positions.

On March 27, 2020, President Trump signed into U.S. federal law the Coronavirus Aid Relief and Economic Security Act (the “CARES Act”), which is aimed at providing emergency assistance and health care for individuals, families, and businesses affected by the COVID-19 pandemic and generally supporting the U.S. economy. The CARES Act, among other things, includes provisions relating to refundable payroll tax credits, deferment of employer side social security payments, net operating loss (“NOL”) carryback periods, alternative minimum tax (“AMT”) credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. In particular, the CARES Act (i) eliminates the 80% of taxable income limitation by allowing corporate entities to fully utilize NOLs to offset taxable income in 2018, 2019 or 2020, (ii) increases the net interest expense deduction limit to 50% of adjusted taxable income from 30% for tax years beginning January 1, 2019 and 2020 and (iv) allows taxpayers with AMT credits to claim a refund in 2020 for the entire amount of the credit instead of recovering the credit through refunds over a period of years, as originally enacted by the Tax Cuts and Jobs Act of 2017. The Company is in the process of analyzing the different aspects of the CARES Act to quantify the impact of these provisions on the Company’s income taxes but expects that there will be no material impact from the CARES Act to the Company’s tax position.

14. EARNINGS (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 warrants, which are measured using the treasury stock method, the conversion feature of the Series A Convertible Preferred Stock, and unvested shares of restricted common stock. When the Company recognizes a net loss attributable to common shareholders, as was the case for the three and six-month periods ended June 30, 2020 and 2019, 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.

The following table presents the weighted-average common share equivalents excluded from the calculation of diluted earnings per share due to their anti-dilutive effect:

15. 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 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.

Warrant Valuation

The warrants contain a dilutive issuance and other provisions that cause the warrants to be accounted for as a liability. Such warrant instruments are initially recorded and valued as a Level 3 liability and are accounted for at fair value with changes in fair value reported in earnings. There were no changes in the methodology to value the warrants. The Company worked with a third-party valuation expert to estimate the value of the warrants at June 30, 2020 and December 31, 2019 using a Lattice model, with the following observable and unobservable inputs:

At June 30, 2020, the Company used the average value calculated by the Lattice model of $193 thousand with a range from $174 thousand to $243 thousand. At December 31, 2019, the Company used the average value of $73 thousand with a range from $60 thousand to $120 thousand. An increase in any of the inputs would cause an increase in the fair value of the warrants. Likewise, a decrease in any input would cause a decrease in the fair value of the warrants.

Marketable Equity Securities Valuation

The fair value of marketable equity securities is based on quoted market prices obtained from independent pricing services. The Company acquired its investment in Anfield as consideration for sales of certain mining operations. Anfield is traded on the TSX Venture Exchange, an active market under the trading symbol AEC:TSXV and has been classified as Level 1.

Other Assets and Liabilities

The Company evaluates the fair value on a non-recurring basis of properties acquired in business combinations. The fair value of the oil and gas properties is determined based upon estimated future discounted cash flow, a Level 3 input, using estimated production which we reasonably expect, and estimated prices adjusted for differentials. Unobservable inputs include estimated future oil and natural gas production, prices, operating and development costs, and a discount rate of 10%, all Level 3 inputs within the fair value hierarchy.

The Company evaluates the fair value on a non-recurring basis of its Riverton, Wyoming real estate assets when circumstances indicate that the value has been impaired. The change in the economic environment due to the COVID-19 pandemic and the property’s remote location has caused a lack of relevant comparable sales to use as a basis for estimating fair value. At June 30, 2020, The Company estimated the fair value of the real estate based upon the expected annual net operating income of the building, estimated capitalization rates for properties in rural areas and values for vacant land based on comparable sales, all Level 3 inputs within the fair value hierarchy.

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.

Recurring Fair Value Measurements

Recurring measurements of the fair value of assets and liabilities as of June 30, 2020 and December 31, 2019 are as follows:

The following table presents a reconciliation of our Level 3 warrants measured at fair value

16. SUBSEQUENT EVENTS UPDATE

Sale of shares in Anfield Energy Inc.

On July 22, 2020, the Company entered into a share purchase agreement to sell 1,210,455 common shares of the Company’s holdings in Anfield Energy Inc. for approximately $45 thousand. Following the sale, the Company owns 2,420,910 shares in Anfield Energy Inc.

Settlement of Texas Litigation

On July 30, 2020, the Company, in their capacity as third-party plaintiffs in the lawsuit against its former President and Chief Executive Officer, David Veltiri, filed a Notice of Voluntary Dismissal of its lawsuit against Mr. Veltri. The Company expects that all matters relating to the Texas Litigation will be dismissed in August 2020.

Arbitration of Employment Claim.

In July 2020, the Company received a request for arbitration from a former employee claiming that the Company breached the former employee’s employment agreement (the “Agreement”) due to a termination of employment without cause. The Agreement requires that any disputes be submitted to binding arbitration. The Company has insurance for these types of claims and has reported the request for arbitration to its insurance carrier. The Company believes it is probable that the insurance carrier will come to a settlement with the former employee and has accrued $100 thousand at June 30, 2020 representing the amount of the insurance deductible.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Forward Looking Statements

This Form 10-Q contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements other than statements of historical facts included in and incorporated by reference into this Form 10-Q are forward-looking statements. When used in this Form 10-Q, the words “will”, “expect”, “anticipate”, “intend”, “plan”, “believe”, “seek”, “estimate” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain these identifying words. Forward-looking statements in this Form 10-Q include statements regarding our expected future revenue, income, production, liquidity, cash flows, reclamation and other liabilities, expenses and capital projects, future capital expenditures and future transactions. Because these forward-looking statements involve risks and uncertainties, actual results could differ materially from those expressed or implied by these forward-looking statements due to a variety of factors, including those associated with our ability to find oil and natural gas reserves that are economically recoverable, the volatility of oil, natural gas liquids and natural gas prices, declines in the values of our properties that have resulted in and may in the future result in additional ceiling test write downs, our ability to replace reserves and sustain production, our estimate of the sufficiency of our existing capital sources, our ability to raise additional capital to fund cash requirements for our participation in oil and gas properties and for future acquisitions, the uncertainties involved in estimating quantities of proved oil and natural gas reserves, in prospect development and property acquisitions or dispositions and in projecting future rates of production or future reserves, the timing of development expenditures and drilling of wells, hurricanes and other natural disasters and the operating hazards attendant to the oil and gas and minerals businesses. In particular, careful consideration should be given to cautionary statements made in the “Risk Factors” section of our 2019 Annual Report on Form 10-K and other quarterly reports on Form 10-Q filed with the SEC, all of which are incorporated herein by reference. The Company undertakes no duty to update or revise any forward-looking statements.

General Overview

U.S. Energy Corp. (“U.S. Energy”, the “Company”, “we” or “us”) is a Wyoming corporation organized in 1966. We are an independent energy company focused on the acquisition and development of oil and natural gas producing properties in the continental United States. Our business activities are currently focused in South Texas and the Williston Basin in North Dakota.

We have historically explored for and produced oil and natural gas through a non-operator business model. As a non-operator, we rely on our operating partners to propose, permit, drill, complete and produce oil and natural gas wells. Before a well is drilled, the operator provides all oil and natural gas interest owners in the designated well the opportunity to participate in the drilling and completion costs and revenues of the well on a pro-rata basis. Our operating partners also produce, transport, market and account for all oil and natural gas production.

Recent Developments

On July 22, 2020, the Company entered into a share purchase agreement to sell 1,210,455 common shares of the Company’s holdings in Anfield Energy Inc. for approximately $45 thousand. Following the sale, the Company owns 2,420,910 shares in Anfield Energy Inc., which it expects to sell during the three months ended September 30, 2020.

Impacts of COVID-19 Pandemic and Effect on Economic Environment

In early March 2020, there was a global outbreak of COVID-19 that has resulted in a drastic decline in global demand of certain mineral and energy products including crude oil. As a result of the lower demand caused by the COVID-19 pandemic and the oversupply of crude oil, spot and future prices of crude oil fell to historic lows during the second quarter of 2020 and remain depressed. Operators in North Dakota’s Williston Basin responded by significantly decreasing drilling and completion activity and shutting in or curtailing production from a significant number of producing wells. Operators decisions on these matters are changing rapidly and it is difficult to predict the future effects on the Company’s business. Lower oil and natural gas prices not only decrease our revenues, but an extended decline in oil or gas prices may materially and adversely affect our future business, financial position, cash flows, results of operations, liquidity, ability to finance planned capital expenditures and the oil and natural gas reserves that we can economically produce.

At June 30, 2020, we performed an impairment review resulting in the Company recording a ceiling test write down of $1.8 million due to the effect lower crude oil prices had on the value of its proved reserves. In the calculation of the ceiling test as of June 30, 2020, the Company used $47.17 per barrel for oil and $2.07 per mcf for natural gas (as further adjusted for differentials related to 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%. These prices represent the average of first day of the month prices for oil and natural gas for each month in the twelve-month period ended June 30, 2020. If depressed prices for crude oil continue, it is likely that the Company will experience additional ceiling test write-downs in 2020 as higher prices from last year and the first three months of 2020 used in the calculation of the average price are replaced with lower prices.

Legal Proceedings

APEG II, our largest shareholder holding approximately 42% of our outstanding common stock, and its general partner, APEG Energy II, GP (together with APEG II, “APEG”), were involved in litigation with us and our former Chief Executive Officer, David Veltri. On July 29, 2020 APEG filed a Notice of Voluntary Dismissal in their lawsuit against us and Mr. Veltri and on July 30, 2020, we filed a Notice of Voluntary Dismissal in our Lawsuit against Mr. Veltri. We expect the litigation will be formally dismissed in August 2020. For more detail regarding such litigation, please see the sections Litigation—APEG II Litigation and –Litigation with Former Chief Executive Officer in Note 9—Commitments, Contingencies and Related-Party Transactions in the Notes to the Unaudited Condensed Consolidated Financial Statements included in Part I, Item 1 of this report.

In July 2020, we received a request for arbitration from a former employee claiming that we breached the former employee’s employment agreement (the “Agreement”) due to a termination of employment without cause. The Agreement requires that any disputes be submitted to binding arbitration. We have insurance for these types of claims and have reported the request for binding arbitration to our insurance carrier. We believe it is probable that the insurance carrier will come to a settlement with the former employee and have accrued $100 thousand at June 30, 2020, representing the amount of our insurance deductible.

Critical Accounting Policies and Estimates

The preparation of our condensed consolidated financial statements in conformity with generally accepted accounting principles in the United States (“GAAP”) requires us to make assumptions and estimates that affect the reported amounts of assets, liabilities, revenues and expenses, as well as the disclosure of contingent assets and liabilities at the date of our financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results may differ from these estimates under different assumptions or conditions. A summary of our significant accounting policies is detailed in Part II, Item 7 – Management’s Discussion and Analysis of Financial Condition and Results of Operations of our 2019 Annual Report on Form 10-K filed with the SEC on March 30, 2020.

Recently Issued Accounting Standards

Please refer to the section entitled Recently Adopted Accounting Pronouncements under Note 1 – Organization, Operations and Significant Accounting Policies in the Notes to the Unaudited Condensed Consolidated Financial Statements included in Part I, Item 1 of this report for additional information on recently issued accounting standards and our plans for adoption of those standards.

Results of Operations

Comparison of our Statements of Operations for the Three Months Ended June 30, 2020 and 2019

During the three months ended June 30, 2020, we recorded a net loss of $3,651 thousand as compared to net income of $20 thousand for the three months ended June 30, 2019. In the following sections we discuss our revenue, operating expenses and non-operating income for the three months ended June 30, 2020 compared to the three months ended June 30, 2019.

Revenue. Presented below is a comparison of our oil and gas sales, production quantities and average sales prices for the three months ended June 30, 2020 and 2019 (dollars in thousands, except average sales prices):

The decrease in our oil and gas revenue of $1,683 thousand for the three months ended June 30, 2020 as compared to the three months ended June 30, 2019 was due to a decrease in oil production of 60% and decrease in the realized price received for our oil production of 71%. The decline in oil prices is primarily due to reduced demand on a global basis beginning in mid-March 2020 as a result of the COVID 19 pandemic. In addition, our oil price differential widened significantly, particularly for our North Dakota properties where the differential from WTI increased to $10.55 per barrel as compared to $4.62 per barrel in the comparable period in 2019. The decrease in oil production volumes is primarily the result of operators shutting in production on our North Dakota properties as a response to low oil prices and the production declines from our South Texas wells drilled in late 2018 and early 2019.

For the three months ended June 30, 2020, we produced 13,897 BOE, or an average of 153 BOE per day, as compared to 39,410 BOE or 433 BOE per day during the comparable period in 2019. This decrease was mainly attributable to North Dakota operators shutting in production as the result of low prices and the production declines from the previously mentioned South Texas wells.

Oil and Gas Production Costs. Presented below is a comparison of our oil and gas production costs for the three months ended June 30, 2020 and 2019 (dollars in thousands):

For the three months ended June 30, 2020, production taxes decreased by $105 thousand, or 89%, compared to the comparable period in 2019. This decrease was primarily attributable to the decrease in oil revenues. During the three months ended June 30, 2020, lease operating expenses decreased by $138 thousand when compared to the three months ended June 30, 2019 due to operators shutting in production, cost cutting measures enacted due to low commodity prices and reduced field activity.

Depreciation, Depletion and Amortization. Our depreciation, depletion and amortization (“DD&A”) rate for the three months ended June 30, 2020 was $6.45 per BOE compared to $4.98 per BOE for the three months ended June 30, 2019. For the most recently completed quarter, our depletion rate was impacted by a reclassification of $2.1 million of our unevaluated properties and the reduction in reserve quantities, primarily due to pricing revisions. Our DD&A rate can fluctuate because of changes in drilling and completion costs, impairments, divestitures, changes in the mix of our production, the underlying proved reserve volumes and estimated costs to drill and complete proved undeveloped reserves.

Impairment of Oil and Natural Gas Properties. During the three months ended June 30, 2020 we recorded impairment of $1.8 million due to the net capitalized cost of our oil and natural gas properties exceeding the full cost ceiling limitation. During the three months ended June 30, 2019 there was no such full cost ceiling limitation.

General and Administrative Expenses. Presented below is a comparison of our general and administrative expenses for the three months ended June 30, 2020 and 2019 (dollars in thousands):

General and administrative expenses decreased by $913 thousand during three-month period ended June 30, 2020 as compared to the prior year period primarily due to a reduction in professional fees. The decrease was primarily attributable to a reduction in legal fees of $931 thousand including the removal of $250 thousand for litigation settlement accruals. The APEG litigation is expected to be dismissed in August 2020 without us incurring certain estimated legal costs. Also included in legal fees is an accrual of $100 thousand for a claim from a former employee that will go to arbitration. In the prior year period, we incurred legal costs of $787 thousand primarily as a result of the APEG II litigation. See Litigation—APEG II Litigation and –Litigation with Former Chief Executive Officer in Note 9—Commitments, Contingencies and Related-Party Transactions in the Notes to the Financial Statements included in Part I, Item 1 of this report. Accounting fees also decreased $120 thousand during the three months ended June 30, 2020 when compared to the prior year period. These decreases in professional fees were partially offset by an increase in compensation and benefits of $108 thousand due to amortization of stock-based compensation awards granted to our Chief Executive Officer and members of our Board in January 2020.

Non-Operating Income (Expense). Presented below is a comparison of our non-operating income (expense) for the three months ended June 30, 2020 and 2019 (dollars in thousands):

During the three months ended June 30, 2020 we reclassified our Riverton, Wyoming building and the related parcel of land to real estate held for sale. Concurrent with the reclassification we recognized a $651 thousand loss to record the value of the building at $725 thousand, representing the amount we expect to realize for the sale of the property. See Note 3—Real Estate Held for Sale in the Notes to the condensed consolidated financial statements included in Part I, Item 1 of this report.

During the three months ended June 30, 2020 we recorded impairment of $403 thousand related to three land parcels totaling 13.85 acres that we own in Riverton, Wyoming, which are not currently offered for sale.

During the three months ended June 30, 2020 we recognized an unrealized loss on marketable equity securities of $46 thousand as compared to a loss of $8 thousand for the comparable period of 2019. The unrealized losses represent the decline in value of our investment in Anfield Energy Inc. In July 2020, we sold 1,210,455 shares, representing one-third of our total investment, for proceeds of $45 thousand. We expect to sell the remaining shares in the third quarter of 2020.

During the three months ending June 30, 2020, we recognized a warrant revaluation loss of 114 thousand as compared to a gain of $234 thousand during the three months ending June 30, 2019. The loss during the three months ended June 30, 2020 was attributable to an increase in the warrant liability primarily due to an increase in the value of our common stock during the period.

Interest, net represents the interest related to our insurance premium finance note net of interest earned on cash balances on deposit at our bank.

Comparison of our Statements of Operations for the Six Months Ended June 30, 2020 and 2019

During the six months ended June 30, 2020, we recorded a net loss of $3,957 thousand as compared to net income of $35 thousand for the six months ended June 30, 2019. In the following sections we discuss our revenue, operating expenses and non-operating income for the six months ended June 30, 2020 compared to the six months ended June 30, 2019.

Revenue. Presented below is a comparison of our oil and gas sales, production quantities and average sales prices for the six months ended June 30, 2020 and 2019 (dollars in thousands, except average sales prices):

The decrease in our oil and gas revenue of $2,321 thousand for the six months ended June 30, 2020 as compared to the six months ended June 30, 2019 was due primarily to a decrease in oil production of 42% and decrease in the realized price received for our oil production of 43%. The decline in oil prices is primarily due to reduced demand on a global basis beginning in mid-March 2020 as the result of the COVID 19 pandemic. In addition, our oil price differential widened significantly, particularly for our North Dakota properties where the differential from WTI increased to $6.94 per barrel as compared to $3.41 per barrel in the comparable period in 2019. The decrease in oil production quantities is the result of operators shutting in production in our North Dakota properties beginning in April as a response to low oil prices, and the production declines from our South Texas wells, which were drilled in late 2018 and early 2019.

For the six months ended June 30, 2020, we produced 40,920 BOE, or an average of 225 BOE per day, as compared to 73,639 BOE or 407 BOE per day during the comparable period in 2019. This decrease was mainly attributable to North Dakota operators shutting in production as the result of low prices and the production declines from the previously mentioned South Texas wells.

Oil and Gas Production Costs. Presented below is a comparison of our oil and gas production costs for the six months ended June 30, 2020 and 2019 (dollars in thousands):

For the six months ended June 30, 2020, production taxes decreased by $136 thousand, or 63%, as compared to the comparable period in 2019. This decrease was primarily attributable to the decrease in oil revenues, which decreased by 67% compared to 2019. During the six months ended June 30, 2020, lease operating expenses decreased by $196 thousand when compared to the six months ended June 30, 2019 as the result of operators shutting in production, cost cutting measures enacted due to low commodity prices and reduced field activity.

Depreciation, Depletion and Amortization. Our DD&A rate for the six months ended June 30, 2020 was $4.76 per BOE compared to $4.87 per BOE for the six months ended June 30, 2019. For the six months ended June 30, 2020, our depletion rate was impacted by a reclassification of $2.1 million of our unevaluated properties and the reduction in reserve quantities at June 30, 2020, primarily due to pricing revisions. Our DD&A rate can fluctuate as a result of changes in drilling and completion costs, impairments, divestitures, changes in the mix of our production, the underlying proved reserve volumes and estimated costs to drill and complete proved undeveloped reserves.

Impairment of Oil and Natural Gas Properties. During the six months ended June 30, 2020 we recorded an impairment of $1.8 million due to the net capitalized cost of our oil and natural gas properties exceeding the full cost ceiling limitation. During the six months ended June 30, 2019 there was no such full cost ceiling limitation.

General and Administrative Expenses. Presented below is a comparison of our general and administrative expenses for the six months ended June 30, 2020 and 2019 (dollars in thousands):

General and administrative expenses decreased by $1,189 thousand during six-month period ended June 30, 2020 as compared to the six-month period ended June 30, 2019 due to a reduction in professional fees. The decrease was primarily attributable to a reduction in legal fees of $1,232 thousand, including the removal of $250 thousand for litigation settlement accruals. The APEG litigation is expected to be dismissed in August 2020 without us incurring certain estimated legal costs. Also included in legal fees during the period is an accrual of $100 thousand for a claim from a former employee that will go to arbitration. In the prior year period, we incurred legal costs of $1,084 thousand, primarily as the result of the APEG II litigation. See Litigation—APEG II Litigation and –Litigation with Former Chief Executive Officer in Note 9—Commitments, Contingencies and Related-Party Transactions in the Notes to the Financial Statements included in Part I, Item 1 of this report. Compensation and benefits increased $39 thousand due to amortization of stock-based compensation awards granted to our Chief Executive Officer and directors in January 2020.

Non-Operating Income (Expense). Presented below is a comparison of our non-operating income (expense) for the six months ended June 30, 2020 and 2019 (dollars in thousands):

During the six months ended June 30, 2020 we reclassified our Riverton, Wyoming building and the related parcel of land to real estate held for sale. Concurrent with the reclassification we recognized a $651 thousand loss to adjust the carrying amount of the land and building to its estimated fair value of $725 thousand. See Note 3—Real Estate Held for Sale in the notes to the condensed consolidated financial statements included in Part I, Item 1 of this report.

During the six months ended June 30, 2020 we recorded impairment of $403 thousand related to three land parcels totaling 13.85 acres that we own in Riverton, Wyoming, which are not currently offered for sale.

During the six months ended June 30, 2020 we recognized an unrealized loss on marketable equity securities of $174 thousand as compared to an unrealized gain of $5 thousand for the comparable period of 2019. The unrealized loss represents the decline in value of our investment in Anfield Energy Inc. In July 2020, we sold 1,210,455 shares, representing one-third of our total investment for proceeds of $45 thousand. We expect to sell the remaining shares in the third quarter of 2020.

During the six months ended June 30, 2020, we recognized a warrant revaluation loss of $120 thousand as compared to a gain of $242 thousand during the six months ended June 30, 2019. The loss during the three months ended June 30, 2020 was attributable to an increase in the warrant liability, primarily as a result of the increase in the value of our common stock.

During the six months ended June 30, 2020, we recognized a gain of $25 thousand from the partial recovery of a deposit written off in 2018. For the six months ended June 30, 2019 we recognized a $50 thousand gain related to the recovery of the same deposit. See Note 7-Write-Off of Deposit in the notes to the condensed consolidated financial statements included in Part I, Item 1 of this report.

Interest, net decreased by $18 thousand during the six months ended June 30, 2020 compared to the comparable period in 2019. The decrease was attributable to the reduction in the principal balance of our credit facility, which was repaid in full on March 1, 2019.

Non-GAAP Financial Measures- Adjusted EBITDAX

Adjusted EBITDAX represents income (loss) from continuing operations as further modified to eliminate depreciation, depletion accretion and amortization, impairment, stock-based compensation expense, unrealized gains and loss on marketable equity securities, gains and losses on warrant revaluation, unrealized losses on the reclassification of real estate to held for sale, interest expense net of interest income, and other items set forth in the table below. Adjusted EBITDAX excludes certain items that we believe affect the comparability of operating results and items that are generally one-time in nature or whose timing and/or amount cannot be reasonably estimated.

Adjusted EBITDAX is a non-GAAP measure that is presented because we believe it provides useful additional information to investors and analysts as a performance measure. In addition, adjusted EBITDAX is widely used by professional research analysts and others in the valuation, comparison, and investment recommendations of companies in the oil and natural gas exploration and production industry, and many investors use the published research of industry research analysts in making investment decisions. Adjusted EBITDAX should not be considered in isolation or as a substitute for net income (loss), income (loss) from operations, net cash provided by operating activities, or profitability or liquidity measures prepared under GAAP. Because adjusted EBITDAX excludes some, but not all items that affect net income (loss) and may vary among companies, the adjusted EBITDAX amounts presented may not be comparable to similar metrics of other companies.

The following table provides reconciliations of income (loss) from continuing operations to adjusted EBITDAX for the six months ended June 30, 2020 and 2019: