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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

(Mark One)

 

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934
   
For the Quarterly Period Ended June 30, 2021
or
   
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934
   
  For the transition period from to

 

Commission File Number 000-06814

 

 

(Exact Name of Registrant as Specified in its Charter)

 

Wyoming   83-0205516
(State or other jurisdiction of   (I.R.S. Employer
incorporation or organization)   Identification No.)

 

675 Bering Dr, Suite 390, Houston, Texas   77057
(Address of principal executive offices)   (Zip Code)

 

Registrant’s telephone number, including area code:   (303) 993-3200

 

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

 

Title of each class   Trading symbol(s)   Name of each exchange on which registered
Common stock, par value $0.01 per share   USEG   The NASDAQ Stock Market LLC (The NASDAQ Capital Market)

 

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 ☒ 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 such files). YES ☒ 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.

 

Large accelerated filer ☐   Accelerated filer ☐
Non-accelerated filer   Smaller reporting company
    Emerging growth company

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES ☐ NO ☒

 

The registrant had 4,676,301 shares of its common stock, par value $0.01 per share, outstanding as of August 10, 2021.

 

 

 

 
 

 

TABLE OF CONTENTS

 

    Page
Cautionary Note About Forward-Looking Statements 3
     
Part I. FINANCIAL INFORMATION 4
     
Item 1. Financial Statements 4
  Condensed Consolidated Balance Sheets (unaudited) 4
  Condensed Consolidated Statements of Operations (unaudited) 5
  Condensed Consolidated Statements of Changes in Shareholders’ Equity (unaudited) 6
  Condensed Consolidated Statements of Cash Flows (unaudited) 7
  Notes to Condensed Consolidated Financial Statements 8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations 21
Item 3. Quantitative and Qualitative Disclosures About Market Risk 30
Item 4. Controls and Procedures 30
     
Part II. OTHER INFORMATION 31
     
Item 1. Legal Proceedings 31
Item 1A. Risk Factors 31
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds 31
Item 3. Defaults Upon Senior Securities 31
Item 4. Mine Safety Disclosures 31
Item 5. Other Information 31
Item 6. Exhibits 32
     
Signatures 33

 

 2 
Table of Contents 

 

Cautionary Note About Forward-Looking Statements

 

This Quarterly Report on Form 10-Q (this “Report” or “Form 10-Q”), including “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”) and the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical facts are forward-looking statements.

 

Examples of forward-looking statements in this Report include:

 

  planned capital expenditures for oil and natural gas exploration and environmental compliance;
     
  potential drilling locations and available spacing units, and possible changes in spacing rules;
     
  cash expected to be available for capital expenditures and to satisfy other obligations;
     
  recovered volumes and values of oil and natural gas approximating third-party estimates;
     
  anticipated changes in oil and natural gas production;
     
  drilling and completion activities and opportunities;
     
  timing of drilling additional wells and performing other exploration and development projects;
     
  expected spacing and the number of wells to be drilled with our oil and natural gas industry partners;
     
  when payout-based milestones or similar thresholds will be reached for the purposes of our agreements with our partners;
     
  expected working and net revenue interests, and costs of wells, relating to the drilling programs with our partners;
     
  actual decline rates for producing wells;
     
  future cash flows, expenses and borrowings;
     
  pursuit of potential acquisition opportunities;
     
  economic downturns and possible recessions caused thereby (including as a result of COVID-19);
     
  the effects of global pandemics, such as COVID-19 on our operations, properties, the market for oil and gas, and the demand for oil and gas;
     
  our expected financial position;
     
  our expected future overhead reductions;
     
  our ability to become an operator of oil and natural gas properties;
     
  our ability to raise additional financing and acquire attractive oil and natural gas properties; and
     
  other plans and objectives for future operations,

 

as well as other statements regarding our future operations, financial condition and prospects, and business strategies. Forward-looking statements may appear throughout this report and other documents we file with the Securities and Exchange Commission (“SEC”), including without limitation, the following sections: Part I, Item 2 , “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this Quarterly Report on Form 10-Q and Part I, Item 1A, “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020, as may be updated in our subsequent Quarterly Reports on Form 10-Q. Forward-looking statements generally can be identified by words such as “anticipates,” “believes,” “estimates,” “expects,” “intends,” “plans,” “predicts,” “projects,” “will be,” “will continue,” “may,” “could,” “will likely result,” and similar expressions. These forward-looking statements are based on current expectations and assumptions that are subject to risks and uncertainties, which could cause our actual results to differ materially from those reflected in the forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed in this Quarterly Report on Form 10-Q, and in particular, under and incorporated by reference in, “Risk Factors”, below, the risks discussed in Part I, Item 1A, “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020, and those discussed in other documents we file with the SEC. We undertake no obligation to revise or publicly release the results of any revision to these forward-looking statements, except as required by law. Given these risks and uncertainties, readers are cautioned not to place undue reliance on such forward-looking statements.

 

 3 
Table of Contents 

 

Part I. FINANCIAL INFORMATION

 

Item 1. Financial Statements

 

U.S. ENERGY CORP. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except share and per share amounts)

 

  

June 30,

2021

  

December 31,

2020

 
         
ASSETS          
Current assets:          
Cash and equivalents  $6,582   $2,854 
Oil and natural gas sales receivable   722    514 
Marketable equity securities   254    181 
Prepaid and other current assets   452    184 
Real estate assets held for sale, net of selling costs   975    975 
           
Total current assets   8,985    4,708 
           
Oil and natural gas properties under full cost method:          
Unevaluated properties   1,598    1,597 
Evaluated properties   94,723    93,549 
Less accumulated depreciation, depletion, amortization and impairment   (87,933)   (87,708)
           
Net oil and natural gas properties   8,388    7,438 
           
Other assets:          
Property and equipment, net   47    25 
Right-of-use asset   167    127 
Other assets   40    65 
           
Total other assets   254    217 
           
Total assets  $17,627   $12,363 
           
LIABILITIES AND SHAREHOLDERS’ EQUITY          
Current liabilities:          
Accounts payable and accrued liabilities  $810   $1,457 
Accrued compensation and benefits   187    312 
Commodity derivative   170    - 
Related party secured note payable   -    375 
Insurance premium note payable   176    - 
Current lease obligation   107    65 
Warrant liability   119    - 
           
Total current liabilities   1,569    2,209 
           
Noncurrent liabilities:          
Asset retirement obligations   1,492    1,408 
Warrant liability   -    95 
Long-term lease obligation, net of current portion   78    78 
Other long-term liabilities   6    6 
Total noncurrent liabilities   1,576    1,587 
           
Total liabilities   3,145    3,796 
           
Commitments and contingencies (Note 9)   -    - 
           
Shareholders’ equity:          
Common stock, $0.01 par value; unlimited shares authorized; 4,676,301 and 3,317,893 shares issued and outstanding at June 30, 2021 and December 31, 2020, respectively   47    33 
Additional paid-in capital   148,922    142,652 
Accumulated deficit   (134,487)   (134,118)
           
Total shareholders’ equity   14,482    8,567 
           
Total liabilities and shareholders’ equity  $17,627   $12,363 

 

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

 

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U.S. ENERGY CORP. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2021 AND 2020

(In thousands, except share and per share amounts)

 

    1    2    3    4 
   Three Months Ended   Six Months Ended 
   June 30,   June 30, 
   2021   2020   2021   2020 
                 
Revenue:                    
Oil  $1,507   $201   $2,639   $1,056 
Natural gas and liquids   149    (12)   228    56 
                     
Total revenue   1,656    189    2,867    1,112 
                     
Operating expenses:                    
Oil and gas operations:                    
Lease operating expenses   477    333    1,045    742 
Production taxes   131    13    210    80 
Depreciation, depletion, accretion and amortization   146    99    264    210 
Impairment of oil and natural gas properties   -    1,794    -    1,794 
General and administrative expenses   812    367    1,547    939 
                     
Total operating expenses   1,566    2,606    3,066    3,765 
                     
Operating income (loss)   90    (2,417)   (199)   (2,653)
                     
Other income (expense):                    
Loss on real estate held for sale   -    (1,054)   -    (1,054)
Derivative loss   (317)   -    (210)   - 
Gain (loss) on marketable equity securities   23    (46)   73    (121)
Warrant revaluation loss   (4)   (114)   (24)   (120)
Rental property gain (loss), net   6    (18)   23    (35)
Other income   1    -    26    28 
Interest, net   (6)   (2)   (58)   (2)
                     
Total other (expense) income   (297)   (1,234)   (170)   (1,304)
                     
Net loss  $(207)  $(3,651)  $(369)  $(3,957)
Accrued preferred stock dividends   -    (103)   -    (203)
Net loss applicable to common shareholders  $(207)  $(3,754)  $(369)  $(4,160)
Basic and diluted weighted shares outstanding   4,676,301    1,399,754    4,304,612    1,379,823 
Basic and diluted loss per share  $(0.04)  $(2.68)  $(0.09)  $(3.01)

 

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

 

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U.S. ENERGY CORP. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CHANGES

IN SHAREHOLDERS’ EQUITY

FOR THE SIX MONTHS ENDED JUNE 30, 2021 AND 2020

(in thousands, except share amounts)

 

         1    2    3    4 
       Additional         
   Common Stock   Paid-in   Accumulated     
   Shares   Amount   Capital   Deficit   Total 
                     
Balances, December 31, 2020   3,317,893   $33   $142,652   $(134,118)  $8,567 
Issuance of shares in underwritten offering, net of offering costs of $488   1,131,600    11    5,272    -    5,283 
Issuance of shares for related party secured note payable conversion   97,962    1    437    -    438 
Issuance of shares for settlement of related party legal costs   90,846    1    405    -    406 
Issuance of shares upon vesting of restricted stock awards   47,000    1    (1)   -    - 
Shares withheld to settle tax withholding obligations for restricted stock awards   (9,000)   -    (38)   -    (38)
Stock-based compensation   -    -    79    -    79 
Net loss   -    -    -    (162)   (162)
                          
Balances, March 31, 2021   4,676,301   $47   $148,806   $(134,280)  $14,573 
Stock-based compensation   -    -    116    -    116 
Net loss   -    -    -    (207)   (207)
                          
Balances, June 30, 2021   4,676,301   $47   $148,922   $(134,487)  $14,482 
                          
Balances, December 31, 2019   1,340,583   $13   $136,876   $(127,679)  $9,210 
Settlement of fractional shares in cash   (327)   -    (1)   -    (1)
Shares issued in acquisition of New Horizon Resources   59,498    1    239    -    240 
Share-based compensation   -    -    42    -    42 
Net loss   -    -    -    (306)   (306)
Balances, March 31, 2020   1,399,754    14    137,156    (127,985)   9,185 
Stock-based compensation   -    -    64    -    64 
Net loss   -    -    -    (3,651)   (3,651)
                          
Balances, June 30, 2020   1,399,754    14    137,220    (131,636)   5,598 

 

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

 

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U.S. ENERGY CORP. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE SIX MONTHS ENDED JUNE 30, 2021 AND 2020

(in thousands)

 

   2021   2020 
         
Cash flows from operating activities:          
Net loss  $(369)  $(3,957)
Adjustments to reconcile net loss to net cash used in operating activities:          
Depreciation, depletion, accretion, and amortization   264    271 
Impairment of oil and gas properties   -    1,794 
Loss on real estate held for sale   -    1,054 
Unrealized loss on commodity derivatives   170    - 
(Gain) loss on marketable equity securities   (73)   121 
Loss on warrant revaluation   24    120 
Loss on related party debt conversion and settlement of legal costs   76      
Stock-based compensation   195    106 
Right of use asset amortization   42    26 
Changes in operating assets and liabilities:          
Decrease (increase) in:          
Oil and natural gas sales receivable   (208)   666 
Other assets   (39)   (51)
Increase (decrease) in:          
Accounts payable and accrued liabilities   (509)   (508)
Accrued compensation and benefits   (125)   (84)
Payments on operating lease liability   (39)   (28)
           
Net cash used in operating activities   (591)   (470)
           
Cash flows from investing activities:          
Acquisition of New Horizon Resources, net of cash acquired   -    (122)
Oil and natural gas capital expenditures   (904)   (31)
Proceeds from sale of oil and gas properties   30    - 
Property and equipment expenditures   (23)   - 
Payment received on note receivable   20    20 
           
Net cash used in investing activities:   (877)   (133)
           
Cash flows from financing activities:          
Proceeds from sale of common stock, net of issuance costs   5,283    - 
Repayment of credit facility   -    (61)
Repayments of insurance premium finance note payable   (48)   (90)
Shares withheld to settle tax withholding obligations for restricted stock awards   (39)   - 
Payment for fractional shares in reverse stock split   -    (1)
           
Net cash provided by (used in) financing activities   5,196    (152)
           
Net increase (decrease) in cash and equivalents   3,728    (755)
           
Cash and equivalents, beginning of period   2,854    1,532 
           
Cash and equivalents, end of period  $6,582   $777 
           
Supplemental disclosures of cash flow information and non-cash activities:          
Cash payments for interest  $3   $2 
Investing activities:          
Issuance of stock in acquisition of New Horizon Resources   -    240 
Change in capital expenditure accruals   256    (9)
Addition of operating lease liability and right of use asset   82    - 
Asset retirement obligations   44    (151)
Financing activities:          
Issuance of stock for conversion of related party secured note payable and accrued interest   438    - 
Issuance of stock for settlement of related party legal costs   406    - 
New Horizon credit facility assumed   -    61 
Financing of insurance premiums with note payable   223    199 

 

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

 

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U.S. ENERGY CORP. AND SUBSIDIARIES

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 and New Horizon Resources, LLC, 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 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 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, 2020, as filed with the SEC on March 26, 2021. Our financial condition as of June 30, 2021, and operating results for the three and six months ended June 30, 2021, 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, 2021.

 

Use of Estimates

 

The preparation of financial statements in conformity with generally accepted accounting principles in the United States (“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; futures prices of commodities used in the valuation of commodity derivative contracts; valuation of warrant instruments; valuation of real estate assets held for sale; 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.

 

Significant Accounting Policies

 

The Company does not designate commodity derivative contracts as cash flow hedges, and therefore the contracts do not qualify for hedge accounting. Changes in fair value of derivative contracts are recorded in the condensed consolidated statement of operations. The fair value of derivative contracts are recorded as either an asset or a liability on the condensed consolidated balance sheet.

 

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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.

 

2. ACQUISITIONS

 

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 “New Horizon Properties”). The Company accounted for the acquisition of the New Horizon Properties as a business combination. The consideration paid at closing consisted of 59,498 shares of the Company’s restricted common stock, $150,000 in cash and the assumption of certain liabilities (the “New Horizon Acquisition”). The New Horizon Acquisition gives the Company operated properties in its core area of operations. The New Horizon 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.

 

   Amount 
    (in thousands) 
Fair value of net assets:     
Proved oil and natural gas properties  $564 
Other current assets   14 
Other long-term assets   58 
Total assets acquired   636 
Asset retirement obligations   (163)
Current payables   (50)
Credit facility   (61)
Net assets acquired  $362 
Fair value of consideration paid for net assets:     
Cash consideration  $150 
Issuance of common stock (59,498 shares at $4.04 per share)   240 
Cash acquired   (28)
Total fair value of consideration transferred  $362 

 

For the six months ended June 30, 2021, the Company recorded revenues of approximately $93 thousand, and lease operating and workover expenses of approximately $30 thousand related to the New Horizon Properties. Assuming that the acquisition of the New Horizon properties had occurred on January 1, 2020, the Company would have recorded revenues of $65 thousand and expenses of $91 thousand for the six months ended June 30, 2020. These results are not necessarily indicative of the results that would have occurred had the Company completed the acquisition on the date indicated, or that will be attained in the future. Subsequent to the closing of the New Horizon Acquisition, the Company repaid the outstanding liabilities assumed at closing.

 

FieldPoint Petroleum

 

On September 25, 2020, the Company acquired certain oil and gas properties primarily located in Lea County, New Mexico and Converse County, Wyoming. The properties were acquired from FieldPoint Petroleum Corporation (“FieldPoint”) pursuant to FieldPoint’s Chapter 7 bankruptcy process (the “FieldPoint Properties”). The Company accounted for the acquisition of the FieldPoint Properties as an asset acquisition. The total amount paid for the FieldPoint Properties was $597 thousand, which includes the purchase price of $500 thousand and transaction costs of $97 thousand, of which $29 thousand were paid via the issuance of 7,075 shares of the Company’s common stock. The Company also recorded purchase price adjustments of $31 thousand for net revenues received, less operating expenses related to periods prior to the closing of the transaction. In addition, the Company recorded asset retirement obligations of $203 thousand for the assets acquired. Substantially all of the value of the acquired FieldPoint Properties consist of mature proved developed producing reserves. Following is a summary of the amounts recorded for the assets acquired:

 

   Amount 
    (in thousands) 
Amounts incurred:     
Cash consideration  $500 
Transaction costs   97 
Purchase price adjustments   (31)
Total consideration paid   566 
      
Asset retirement obligations assumed   203 
      
Total evaluated property  $769 

 

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Acquisition of Liberty County Properties

 

On November 9, 2020, the Company entered into a Purchase and Sale Agreement (the “PSA”) to acquire certain assets from Newbridge Resources LLC (“Newbridge”). The transaction closed on December 1, 2020 with an effective date of November 1, 2020. The assets include operated producing properties in Liberty County, Texas (the “Liberty County Properties”). The Liberty County Properties include 41 wells which have a 100% working interest and an average 86% net revenue interest and approximately 680 net acres located primarily in Liberty County, Texas which are 100% held by production. The Company issued 67,254 shares of its common stock, which at the closing price of $4.24 on the date of the closing of the PSA, were valued at $285 thousand, in consideration for the acquisition. The Company accounted for the acquisition of the Liberty County Properties as an asset acquisition. The total amount paid was $326 thousand including transaction costs of $41 thousand. In addition, the Company recorded asset retirement obligations of $192 thousand for the assets acquired. Substantially all of the value of the Liberty County Properties acquired consisted of mature proved developed producing reserves and proved developed non-producing reserves. Following is a summary of the amounts recorded for the assets acquired:

 

   Amount 
    (in thousands) 
Amounts incurred:     
Value of 67,254 shares issued  $285 
Transaction costs   41 
Total consideration paid   326 
      
Asset retirement obligations assumed   192 
      
Total evaluated property  $518 

 

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 and an additional 13-acre parcel of land adjacent to the 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. During the year ended December 31, 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 and the building land was in the range of $700 thousand to $900 thousand and the realizable value of the additional land was in the range of $250 thousand to $300 thousand. A special committee of the board of directors was formed to evaluate the sales process. During 2020, the Company entered into an agreement with a large national commercial broker and a local broker in Riverton, Wyoming to sell the building and the land. During the year ended December 31, 2020, the Company recognized a loss on the land and building of $1,054 thousand. The Company has accepted an offer to purchase the building and the associated land and expects the sale to be completed in 2021. The following are the estimated fair values and the estimated net proceeds relating to the real estate assets held for sale at June 30, 2021 and December 31, 2020:

 

   Amount 
    (in thousands) 
      
Fair value of real estate held for sale:     
Estimated sales price of building and land  $800 
Estimated sales price of additional land   275 
Estimated cost to sell   (100)
Estimated net proceeds  $975 

 

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4. REVENUE RECOGNITION

 

The Company’s revenues are primarily derived from its non-operated 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 consolidated balance sheets. Variances between the Company’s estimated revenue and actual payments are recorded in the month the payment is received. 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.

 

During 2020, the Company acquired operated oil and gas producing properties (see Note 2- Acquisitions, above). The Company sells its oil production at the delivery point specified in the contract and 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 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 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 unaudited condensed consolidated statements of operations. The revenue and costs in the consolidated statements of operations were reported gross for the three and six months ended June 30, 2021 and 2020, as the gross amounts were known.

 

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The Company’s operated revenues are growing. Operated revenues for the three months ended June 30, 2021, and 2020 were 32% and 14% of total revenues, respectively. The Company’s operated revenues for the six months ended June 30, 2021, and 2020 were 32% and 3%, respectively. The Company disaggregates total revenues from its share of revenue from the sale of oil and natural gas and liquids by state. The Company’s revenues in North Dakota, Texas, New Mexico and other states for the three and six months ended June 30, 2021 and 2020, are presented in the following table:

 

   Three Months Ended
June 30,
   Six Months Ended
June 30,
 
   2021   2020   2021   2020 
   (in thousands) 
Revenue:                
North Dakota                    
Oil  $698   $142   $1,221   $631 
Natural gas and liquids    68    (17)   148    32 
Total  $766   $125   $1,369   $663 
                     
Texas                    
Oil  $615   $59   $1,118   $425 
Natural gas and liquids   80    5    98    24 
Total  $695   $64   $1,216   $449 
                     
New Mexico                    
Oil  $98   $-   $212   $- 
Natural gas and liquids   -    -    -    - 
Total  $98   $-   $212   $- 
                     
Other                    
Oil  $96   $-   $88   $- 
Natural gas and liquids   1    -    (18)   - 
Total  $97   $-   $70   $- 
                     
Total revenue  $1,656   $189   $2,867   $1,112 

 

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 and by joint interest operators of the Company’s oil and natural gas properties. The following table presents the purchasers and 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:

 

Operator  2021   2020 
Zavanna, LLC   37%   44%
Infinity Hydrocarbons, LLC   29%   3%
CML Exploration, LLC   10%   37%

 

5. LEASES

 

During the six months ended June 30, 2021, the Company acquired right-of-use assets and operating lease liability of $82 thousand associated with entering into a non-cancellable, long-term lease agreement for office space in Houston, Texas. The Company’s right-of-use assets and lease liabilities are recognized at their discounted present value under the following captions in the consolidated balance sheets at June 30, 2021 and December 31, 2020:

 

      1       2  
   

June 30,

2021

   

December 31,

2020

 
    (in thousands)  
Right of use asset balance                
Operating lease   $ 167     $ 127  
Lease liability balance                
Short-term operating lease   $ 107     $ 65  
Long-term operating lease     78       78  
Total operating leases    $ 185     $ 143  

 

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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, Texas office lease, prior to February 2021, when the Company entered into a new 25-month lease for its Houston office. Beginning in March 2020, the Company subleased its Denver, Colorado office and recognizes sublease income as a reduction of rent expense. Following are the amounts recognized as components of rental expense for the three and six months ended June 30, 2021 and 2020:

 

      2021       2020       2021       2020  
    Three Months Ended
June 30,
    Six Months Ended
June 30,
 
    2021     2020     2021     2020  
    (in thousands)  
Operating lease cost   $ 27     $ 17     $ 51     $ 34  
Short-term lease cost     12       6       18       10  
Sublease income     (16 )     (11 )     (32 )     (16 )
Total lease costs   $ 23     $ 12     $ 37     $ 28  

 

The Company’s Denver and Houston office operating leases do 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.

 

   As of June 30, 
   2021   2020 
     
Weighted average lease term (years)   1.7    2.6 
Weighted average discount rate   9.26%   8.75%

 

The future minimum lease commitments as of June 30, 2021, are presented in the table below in thousands. Such commitments are reflected at undiscounted values and are reconciled to the discounted present value on the consolidated balance sheet as follows:

 

   Amount 
Remainder of 2021  $60 
2022   122 
2023   17 
Total lease payments   199 
Less: imputed interest   (14)
Total lease liability  $185 

 

As discussed in Note 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 is not depreciated while it is held for sale. The net capitalized cost of the building and the land subject to operating leases at June 30, 2021 and December 31, 2020 are as follows:

 

      1       2  
   

June 30,

2021

   

December 31,

2020

 
    (in thousands)  
Building subject to operating leases   $ 4,654     $ 4,654  
Land     380       380  
Less: accumulated depreciation     (3,658 )     (3,658 )
Loss on leased real estate held for sale     (651 )     (651 )
Building subject to operating leases, net   $ 725     $ 725  

 

The future lease maturities of the Company’s operating leases as of June 30, 2021 are presented in the table below. Such maturities are reflected at undiscounted values to be received on an annual basis.

 

     1 
   Amount 
   (in thousands) 
Remainder of 2021  $82 
2022   165 
2023   169 
2024   163 
Remaining through June 2029   695 
Total lease maturities  $1,274 

 

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The Company recognized, as a component of rental and other loss in the unaudited condensed consolidated statements of operations, the following operating lease income and expense related to its Riverton, Wyoming office building for the three and six months ended June 30, 2021 and 2020:

 

   Three Months Ended
June 30,
   Six Months Ended
June 30,
 
   2021   2020   2021   2020 
   (in thousands) 
Operating lease income  $51   $54   $102   $110 
Operating lease expense   (45)   (43)   (79)   (86)
Depreciation   -    (29)   -    (59)
Rental property gain (loss), net  $6   $(18)  $23   $(35)

 

6. OIL AND NATURAL GAS PRODUCTION ACTIVITIES

 

Divestitures

 

During the six months ended June 30, 2021, the Company sold approximately 12 net acres of undeveloped acreage in Midland County, Texas for approximately $30 thousand. There were no divestures of oil and natural gas producing properties during the six months ended June 30, 2020.

 

Ceiling Test and Impairment

 

The Company did not record a ceiling test write-write down of its oil and natural gas properties during the six months ended June 30, 2021. During the six months ended June 30, 2020, the Company recorded a ceiling test write down of $1.8 million. 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, 2021, the Company used $49.78 per barrel for oil and $2.43 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%.

 

7. DEBT

 

On March 4, 2021, the Company closed a Debt Conversion Agreement (the “Conversion Agreement”) with APEG Energy II, L.P.( “APEG II”), over which entity Patrick E. Duke, a former director of the Company, has shared voting power and shared investment power. The Conversion Agreement was related to a $375,000 related party secured note payable the Company borrowed from APEG II on September 24, 2020 (the “Note”). The Note accrued interest at 10% per annum and had a maturity date of September 24, 2021. The Note was secured by the Company’s wholly-owned subsidiary, Energy One’s oil and natural gas producing properties. Under the terms of the Note, the Company may repay the Note prior to maturity, however, in the event of a prepayment of the Note, the Company was required to pay APEG II the amount of interest which would have accrued through maturity (at 10% per annum). Pursuant to the Conversion Agreement, the Company converted the related party secured note payable of $375,000 and accrued interest to the date of the Note’s September 24, 2021 maturity of $37,500 by issuing 97,962 shares of unregistered common stock with a value on the date of the Conversion Agreement of $438,000. The difference of $25,500 between the value of the shares issued and the $412,500 amount of the Note and accrued interest through the date of maturity is recorded as interest expense, net, in the condensed consolidated statements of operations.

 

8. COMMODITY DERIVATIVE

 

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, the Company entered into a fixed-price swap commodity derivative contract to protect against price declines in future periods on 100 barrels of crude oil per day from March 1 to December 31, 2021, at $61.90, based on the calendar month average of West Texas Intermediate Crude Oil (“WTI”). There are no collateral requirements for the fixed-price swap derivative contract. The Company does not enter into derivative contracts for speculative purposes. The Company has not elected to designate the fixed-price swap as a cash flow hedge; therefore, the instrument does not qualify for hedge accounting. Accordingly, changes in the fair value of the fixed-price swap contract are recoded in the unaudited condensed consolidated statements of operations and are included in cash flows from operating activities in the condensed consolidated statement of cash flows.

 

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The following table presents the impact of our fixed-price derivative contract on our condensed consolidated statements of operations for the three and six months ended June 30, 2021 and 2020:

 

     2021     2020     2021     2020 
   Three Months Ended
June 30,
   Six Months Ended
June 30,
 
   2021   2020   2021   2020 
   (in thousands) 
Commodity derivative loss, net:                    
Settlements  $(38)  $-   $(40)  $- 
Change in fair value of unsettled derivatives   (279)   -    (170)   - 
Total commodity derivative loss, net  $(317)  $-   $(210)  $- 

 

9. COMMITMENTS, CONTINGENCIES AND RELATED-PARTY TRANSACTIONS

 

Litigation

 

Arbitration of Employment Claim

 

In July 2020, the Company received a request for arbitration from its former Chief Executive Officer, David Veltri claiming that the Company breached his employment agreement. The Company intends to vigorously contest this matter and believes these claims are without merit. The employment 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. Through June 30, 2021, the Company has incurred defense costs in this matter of $117 thousand and has accrued $10 thousand for future defense costs, representing the Company’s responsibility for costs under the insurance policy.

 

APEG II Litigation

 

From February 2019 until August 2020, the Company was involved in litigation with its former Chief Executive Officer, David Veltri and at the time its largest shareholder, APEG II and APEG II’s general partner, APEG Energy II, GP (together with APEG II, “APEG”). In addition, Patrick E. Duke, a former director of the Company, had shared voting and shared investment power over APEG. The litigation arose as a result of a vote at the February 25, 2019 board of directors meeting to terminate Mr. Veltri for using Company funds outside of his authority and for other reasons (the “Texas Litigation”). In a separate lawsuit, APEG initiated a shareholder derivative action in Colorado against Mr. Veltri due to his refusal to recognize the Board’s decision to terminate him (the “Colorado Litigation”). The Company was named as a nominal defendant in the Colorado Litigation. The Colorado litigation was dismissed in May 2020 and the Texas Litigation was dismissed in August 2020. On March 4, 2021, the Company issued 90,846 shares of unregistered common stock, which had a value on the date of issuance of $406 thousand, to APEG in reimbursement of APEG’s legal costs in the Colorado and Texas Litigation.

 

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 of Directors 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 December 31, 2020, the Company redeemed all 50,000 shares of then outstanding Series A Convertible Preferred Stock (the “Preferred Stock”), by making a cash payment of $2.0 million and issuing 328,000 shares of its common stock, which at the date of the redemption had a value of $3.68 per share for a total redemption price of $3.2 million. The liquidation preference on the date of redemption was $3.6 million. The difference between the redemption price and the liquidation preference of the preferred stock was included as a reduction of the net loss available to common shareholders in the calculation of loss per share.

 

The Company had issued the 50,000 shares of Preferred Stock on February 12, 2016, to Mt. Emmons Mining Company (“MEM”), a subsidiary of Freeport McMoRan Inc., 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 of $2 million. The Preferred Stock liquidation preference, initially $2 million, increased by quarterly dividends of 12.25% per annum (the “Adjusted Liquidation Preference”). At the option of the holder, each share of Preferred Stock initially could have been 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. The Conversion Rate was subject to anti-dilution adjustments for stock splits, stock dividends and certain reorganization events and to price-based anti-dilution protections, subject to a price floor.

 

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11. SHAREHOLDERS’ EQUITY

 

Common Stock

 

At June 30, 2021, the Company had 4,676,301 shares of common stock outstanding. On February 17, 2021, the Company sold 1,131,600 shares of common stock for net proceeds of $5.3 million.

 

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, for a period of five years from the final closing date of June 21, 2017. The warrants include anti-dilution rights. The total net proceeds received by the Company were approximately $1.3 million. The fair value of the warrants upon issuance were $1.2 million, with the remaining $0.1 million being attributed to common stock. On September 29, 2020, the Company received proceeds of $565 thousand related to the exercise of warrants to purchase 50,000 shares of 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 remaining warrants to purchase 50,000 shares of common stock was $119 thousand and $95 thousand at June 30, 2021 and December 31, 2020, respectively.

 

Pursuant to the original warrant agreement, as a result of common stock issuances at various prices, the warrant exercise price has been reduced from its original $20.50 exercise price to the floor price of $3.92, which is the exercise price of the warrants at June 30, 2021.

 

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.

 

For the six months ended June 30, 2021 and 2020, there was no compensation expense related to stock options. As of December 31, 2019, all stock options had vested. No stock options were granted or exercised, during the six months ended June 30, 2021 or 2020. During the six months ended June 30, 2021 and 2020, options to purchase 332 shares and 166 shares, respectively, expired. Presented below is information about stock options outstanding and exercisable as of June 30, 2021 and December 31, 2020:

 

    June 30, 2021     December 31, 2020  
    Shares     Price     Shares     Price  
                         
Stock options outstanding and exercisable     31,035     $ 62.79       31,367     $ 64.78  

 

The following table summarizes information for stock options outstanding and for stock options exercisable at June 30, 2021:

 

Options Outstanding   Options Exercisable 
    Exercise Price   Weighted   Remaining       Weighted 
Number of   Range  

Average

Exercise

  

Contractual

Term

   Number of  

Average

Exercise

 
Shares   Low   High   Price   (years)   Shares   Price 
                          
 16,500   $7.20   $11.60   $10.00    6.3    16,500   $10.00 
 10,622    90.00    124.80    106.20    2.8    10,622    106.20 
 2,913    139.20    171.00    147.39    1.0    2,913    147.39 
 1,000    226.20    226.20    226.20    3.2    1,000    226.20 
                                 
 31,035   $7.20   $226.20   $62.79    4.5    31,035   $62.79 

 

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Restricted Stock

 

Company grants restricted stock under its incentive plan covering shares of common stock to employees and directors of the Company. 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. Restricted stock granted to employees, when vested are net settled through the issuance of shares, net of the number of shares required to pay withholding taxes.

 

The following table presents the changes in non-vested, time-based restricted stock awards to all employees and directors for the six months ended June 30, 2021:

 

   Shares  

Weighted-Avg.

Grant Date

Fair Value

per Share

 
     
Non-vested restricted stock at December 31, 2020   71,000   $4.89 
Granted   150,000   $4.72 
Vested   (47,000)  $4.89 
Non-vested at June 30, 2021   174,000   $4.75 

 

The following table presents the stock compensation expense related to restricted stock grants for the three and six months ended June 30, 2021 and 2020:

 

       2021     2020     2021     2020 
   Three Months Ended
June 30,
   Six Months Ended
June 30,
 
   2021   2020   2021   2020 
   (in thousands) 
                     
Stock compensation expense  $116   $64   $195   $106 

 

Total compensation cost related to non-vested time-based awards not yet recognized in the Company’s condensed consolidated statements of operations as of June 30, 2021, is $650 thousand. This cost is expected to be recognized over a weighted average period of 2.6 years.

 

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, 2021 and December 31, 2020:

 

  

June 30,

2021

  

December 31,

2020

 
   (in thousands) 
Balance, beginning of year  $1,408   $819 
Accretion   40    43 
Sold/Plugged   -    (12)
Acquired   44    558 
Balance, end of period  $1,492   $1,408 

 

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 the six months ended June 30, 2021 and 2020.

 

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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 carry-forwards. 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, 2020, the Company maintains a full valuation allowance recorded against all DTAs. The Company, therefore, had no recorded DTAs as of June 30, 2021. 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.

 

At December 31, 2020, the Company had approximately $8.9 million in net operating loss carryovers (after limitations). During the six months ended June 30, 2021 and year ended December 31, 2020, the Company issued approximately 1.3 million and 2.0 million additional shares of common stock, respectively in various transactions. The Company is currently evaluating whether these issuances represented an ownership change that would have triggered a loss limitation under Internal Revenue Code (“I.R.C.”) Section 382. However, since the Company maintains a valuation allowance against these tax assets there is no impact to the condensed consolidated statement of operations for the three and six months ended June 30, 2021.

 

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, 2021 and 2020, no adjustments were recognized for uncertain tax positions.

 

14. 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 Preferred Stock prior to redemption, and unvested shares of restricted common stock. When the Company recognizes a net loss, as was the case for the three and six months ended June 30, 2021 and 2020, 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 and six months ended June 30, 2021 and 2020:

 

     2021     2020     2021     2020 
   Three Months Ended
June 30,
   Six Months Ended
June 30,
 
   2021   2020   2021   2020 
   (in thousands except per share data) 
Net loss  $(207)  $(3,651)  $(369)  $(3,957)
Accrued dividend on Series A preferred stock   -    (103)   -    (203)
Loss applicable to common shareholders  $(207)  $(3,754)  $(369)  $(4,160)
Basic weighted average common shares outstanding   4,676    1,399    4,305    1,380 
Dilutive effect of potentially dilutive securities   -    -    -    - 
Diluted weighted average common shares outstanding   4,676    1,399    4,305    1,380 
                     
Basic net loss per share  $(0.04)  $(2.68)  $(0.09)  $(3.01)
Diluted net loss per share  $(0.04)  $(2.68)  $(0.09)  $(3.01)

 

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:

 

   Three Months Ended
June 30,
   Six Months Ended
June 30,
 
   2021   2020   2021   2020 
   (in thousands) 
Stock options   31    32    31    32 
Unvested shares of restricted stock   174    76    150    65 
Warrants   50    100    50    100 
Series A preferred stock   -    79    -    79 
Total   255    287    231    276 

 

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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 December 31, 2020 using a Black Scholes model, with the following observable and unobservable inputs:

 

  

June 30,

2021

   December 31,
2020
 
     
Number of warrants outstanding   50,000    50,000 
Expiration date   June 21, 2022    June 21, 2022 
Exercise price  $3.92   $3.92 
Beginning share price  $4.74   $3.68 
Dividend yield   0%   0%
Average volatility rate (1)   120%   120%
Probability of down-round event (2)   0%   0%
Risk free interest rate   0.11%   0.11%

 

 

(1) The average volatility represents the Company’s 2-year volatility measurement, the observed volatility of our peer group over a similar period, and the stock market volatility as of the valuation date.
(2) Represents the estimated probability of a future down-round event during the remaining term of the warrants.

 

At June 30, 2021 and December 31, 2020, the Company used the average value calculated by the Black-Scholes model as opposed to a Monte Carlo model, because the strike price is set at the floor of $3.92 and therefore cannot be rounded down further.

 

Marketable Equity Securities

 

The fair value of marketable equity securities is 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.

 

  

June 30,

2021

 
     
Number of shares owned   2,421,180 
Quoted market price  $0.10486 
      
Fair value  $253,896 

 

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Commodity Derivative Instruments

 

During the six months ended June 30, 2021, the Company entered into a fixed-price swap derivative contract. The Company measures the fair value of derivative contracts using an income valuation technique based on the contract price of the underlying positions, crude oil forward curves, discount rates, and counterparty non-performance risk from a marketplace participant’s perspective. The fixed-price swap derivative contract is included in Level 2.

 

Asset Retirement Obligations

 

The Company measures the fair value of asset retirement obligations as of the date a well is acquired or the date a well begins drilling using a discounted cash flow method based on unobservable inputs in the market and therefore are designated as Level 3 within the valuation hierarchy.

 

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, 2021, the Company estimated the fair value of the real estate based upon offers it had received for the real estate, 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, 2021 and December 31, 2020 are as follows:

 

   June 30, 2021   December 31, 2020 
   Level 1   Level 2   Level 3   Total   Level 1   Level 2   Level 3   Total 
   (in thousands) 
Current Assets:                                        
Marketable Equity Securities  $254   $-   $-   $254   $181   $-   $-   $181 
                                         
Current Liabilities:                                        
Commodity derivatives  $-    170    -    170    -    -    -    - 
Warrants   -    -    119    119    -    -    -    - 
    -    170    119    289    -    -    -    - 
                                         
Non-current Liabilities:                                        
Warrants  $-   $-   $-   $-   $-   $-   $95   $95 

 

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

  

Six Months
Ended
June 30,

2021

  

Year Ended
December 31,

2020

 
   (in thousands) 
Fair value liabilities of Level 3 instruments beginning of period  $95   $73 
Loss on warrant valuation   24    22 
Fair value liabilities of Level 3 instruments end of period  $119   $95 

 

 

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

 

Introduction

 

This information should be read in conjunction with the interim unaudited financial statements and the notes thereto included in this Quarterly Report on Form 10-Q, and the audited financial statements and notes thereto and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” contained in our Annual Report on Form 10-K for the year ended December 31, 2020, filed with the Securities and Exchange Commission on March 26, 2021 (the “Annual Report”).

 

Certain abbreviations and oil and gas industry terms used throughout this Report are described and defined in greater detail under “Glossary of Oil and Natural Gas Terms” on page 4 of our Annual Report.

 

Certain capitalized terms used below and otherwise defined below, have the meanings given to such terms in the footnotes to our consolidated financial statements included above under “Part I - Financial Information” – “Item 1. Financial Statements”.

 

In this Quarterly Report on Form 10-Q, we may rely on and refer to information regarding the industries in which we operate in general from market research reports, analyst reports and other publicly available information. Although we believe that this information is reliable, we cannot guarantee the accuracy and completeness of this information, and we have not independently verified any of it.

 

See also “Cautionary Note About “Forward-Looking Statements” above.

 

Unless the context requires otherwise, references to the “Company,” “we,” “us,” “our,” “U.S. Energy”, and “U.S. Energy Corp.” refer specifically to U.S. Energy Corp. and its consolidated subsidiaries

 

In addition, unless the context otherwise requires and for the purposes of this report only:

 

“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;
   
“BOE” refers to barrels of oil equivalent, determined using the ratio of one Bbl of crude oil, condensate or natural gas liquids, to six Mcf of natural gas;
   
“Bopd” refers to barrels of oil day;
   
“Mcf” refers to a thousand cubic feet of natural gas;
   
“Mcfe” means 1,000 cubic feet equivalent, determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or natural gas liquids
   
“NGL” refers to natural gas liquids;
   
“Exchange Act” refers to the Securities Exchange Act of 1934, as amended;
   
“SEC” or the “Commission” refers to the United States Securities and Exchange Commission;
   
“Securities Act” refers to the Securities Act of 1933, as amended; and
   
“WTI” means West Texas Intermediate.

 

Where You Can Find Other Information

 

We file annual, quarterly, and current reports, proxy statements and other information with the SEC. The SEC maintains an Internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC like us at https://www.sec.gov (our filings can be found at https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000101594) and on the “Investors – SEC Filings” page of our website at https://usnrg.com. Copies of documents filed by us with the SEC are also available from us without charge, upon oral or written request to our Secretary, who can be contacted at the address and telephone number set forth on the cover page of this Report.

 

Summary of The Information Contained in Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

Our Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A) is provided in addition to the accompanying consolidated financial statements and notes to assist readers in understanding our results of operations, financial condition, and cash flows. MD&A is organized as follows:

 

  General Overview. Discussion of our business and overall analysis of financial and other highlights affecting us, to provide context for the remainder of MD&A.
     
  Plan of Operations and Strategy. Discussion of our strategy moving forward and how we plan to seek to increase stockholder value.
     
  Recent Developments. Discussion of recent developments affecting the Company and our operations.
     
  Critical Accounting Policies and Estimates. Accounting estimates that we believe are important to understanding the assumptions and judgments incorporated in our reported financial results and forecasts.
     
  Results of Operations. An analysis of our financial results comparing the three and six months ended June 30, 2021, and 2020.
     
  Liquidity and Capital Resources. A discussion of our financial condition, including descriptions of balance sheet information and cash flows.

 

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General Overview

 

U.S. Energy Corp. - 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, the Williston Basin in North Dakota, Lea County in New Mexico and Converse County in Wyoming.

 

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. With recent acquisitions in 2020 of New Horizon Resources, certain FieldPoint Petroleum wells and certain wells in Liberty County, Texas we now operate a small portion of our production.

 

Plan of Operations and Strategy

 

During the remainder of 2021 and beyond, we intend to seek additional opportunities in the oil and natural gas sector, including but not limited to further acquisition of assets, participation with current and new industry partners in their exploration and development projects, acquisition of existing companies, and the purchase of oil producing assets. In addition, we plan to grow production by performing workovers on operated idle wells acquired in 2020 to return them back to production.

 

Key elements of our business strategy include:

 

  Deploy our Capital in a Conservative and Strategic Manner and Review Opportunities to Bolster our Liquidity. In the current industry environment, maintaining liquidity is critical. Therefore, we will be highly selective in the projects we evaluate and will review opportunities to bolster our liquidity and financial position through various means.
     
  Evaluate and Pursue Value-Enhancing Transactions. We plan to continuously evaluate strategic alternative opportunities that we believe will enhance shareholder value.

 

Recent Developments

 

Impacts of COVID-19 Pandemic and Effect on Economic Environment

 

In early March 2020, there was an outbreak of a novel strain of coronavirus, which causes the infectious disease known as COVID-19, which 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, which remained depressed for the majority of 2020. 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, all of which have since come back online. 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.

 

Additionally, the outbreak of COVID-19 and decreases in commodity prices resulting from oversupply, government-imposed travel restrictions, and other constraints on economic activity caused a significant decrease in the demand for oil and has created disruptions and volatility in the global marketplace for oil and gas during the first quarter of 2020, and continuing through most of 2020, which negatively affected our results of operations and cash flows during 2020. While demand and commodity prices have recently recovered and are back to pre-pandemic levels, our financial results may continue to be depressed in future quarters. The extent to which the COVID-19 pandemic impacts our business going forward will depend on numerous evolving factors we cannot reliably predict, including the duration and scope of the pandemic; governmental, business, and individuals’ actions in response to the pandemic; the availability and efficacy of vaccines and boosters, and the willingness of individuals to obtain such vaccines; future virus mutations; and the impact on economic activity including the possibility of recession or financial market instability. These factors may adversely impact the supply and demand for oil and gas and our ability to produce and transport oil and gas and perform operations at and on our properties. This uncertainty also affects management’s accounting estimates and assumptions, which could result in greater variability in a variety of areas that depend on these estimates and assumptions, including investments, receivables, and forward-looking guidance.

 

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Critical Accounting Policies and Estimates

 

The preparation of our unaudited 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 2020 Annual Report on Form 10-K filed with the SEC on March 26, 2021 (the “2020 Annual Report”) and under “Note 1. Organization and Significant Accounting Policies” in the notes to consolidated financial statements included in our 2020 Annual Report.

 

The Company’s results of operations and operating cash flows are affected by changes in market prices for crude oil and natural gas. To manage a portion of our exposure to price volatility from producing crude oil, we entered into a crude oil derivative swap contract during the six months ended June 30, 2021, to protect against price declines in future periods. The Company does not designate commodity derivative contracts as a cash flow hedges and therefore the contract does not qualify for hedge accounting. Changes in fair value of the swap contract are recorded in the condensed consolidated statement of operations. The fair value of the swap contract is recorded as either an asset or a liability on the condensed consolidated balance sheet.

 

Recently Issued Accounting Standards

 

We do not believe that any recently issued but not yet effective accounting standards, if currently adopted, would have a material effect on our Condensed Consolidated Financial Statements or related disclosures.

 

Results of Operations

 

Comparison of our Statements of Operations for the Three Months Ended June 30, 2021 and 2020

 

For the three months ended June 30, 2021, we recorded a net loss of $207 thousand as compared to a net loss of $3,651 thousand for the three months ended June 30, 2020. In the following sections we discuss our revenue, operating expenses and non-operating income for the three months ended June 30, 2021, compared to the three months ended June 30, 2020.

 

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, 2021 and 2020:

 

    Three months ended
June 30,
    Change  
    2021     2020     Amount     Percent  
    (in thousands except average prices and production quantities)  
Revenue:                                
Oil   $ 1,507     $ 201     $ 1,306       650 %
Gas     149       (12 )     161      

Not meaningful

                                 
Total   $ 1,656     $ 189     $ 1,467       776 %
                                 
Production quantities:                                
Oil (Bbls)     24,077       11,710       12,367       106 %
Gas (Mcf)     47,979       13,124       34,855       266 %
BOE     32,073       13,897       18,176       131 %
BOE per day    

352

     

153

     

199

         
                                 
Average sales prices:                                
Oil (Bbls)   $ 62.59     $ 17.18     $ 45.41       264 %
Gas (Mcf)     3.10       (0.95 )     4.05      

Not meaningful

BOE   $ 51.62     $ 13.58     $ 38.04       280 %

 

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The increase in our oil and gas revenue of $1,467 thousand for the three months ended June 30, 2021, as compared to the three months ended June 30, 2020, was due to an increase in oil production of 106% and an increase in the realized price received for our oil production of 264%. The increase in oil prices is primarily due to stronger demand for crude oil on a global basis as the world recovered from government mandated lockdowns which began in mid-March 2020 in order to reduce the spread of the COVID-19 pandemic. The increase in oil production volumes is primarily the result of the acquisitions of properties we completed during 2020, and our efforts in the first six months of 2021 to return idle wells to production. During the three months ended June 30, 2021, we produced 9,472 Bbls of oil from properties acquired in the second half of 2020. In addition, during the three months ended June 30, 2021, we experienced production increases in our legacy non-operated properties, primarily in North Dakota as the result of workovers in which we participated. In the comparable period of the prior year, production declined due to operators, principally in North Dakota, temporarily shutting in production as the result of low commodity prices.

 

For the three months ended June 30, 2021, we produced 32,073 BOE, or an average of 356 BOE per day, as compared to 13,897 BOE or 153 BOE per day during the comparable period in 2020. During the three months ended June 30, 2021, our BOE production mix was 75% oil and 25% natural gas compared to 84% oil and 16% gas in the comparable period of 2020. The increase in gas as a percentage of total production increased due to the acquisition of non-operated gas producing properties in the second half of 2020.

 

Oil and Gas Production Costs. Presented below is a comparison of our oil and gas production costs for the three months ended June 30, 2021 and 2020:

 

    Three months ended
June 30,
    Change  
    2021     2020     Amount     Percent  
    (in thousands)  
Production taxes   $ 131     $ 13     $ 118       908 %
Lease operating expense     477       333       144       43 %
                                 
Total   $ 608     $ 346     $ 262       76 %

 

For the three months ended June 30, 2021, production taxes increased by $118 thousand, or 908%, compared to the comparable period in 2020. This increase was attributable to the increase in oil revenues of 776% from the three months ended June 30, 2020. For the three months ended June 30, 2021, lease operating expenses increased by $144 thousand when compared to the three months ended June 30, 2020, due to increased activity as the result of operated properties acquired in the second half of 2020.

 

Depreciation, Depletion and Amortization. Our depreciation, depletion and amortization (“DD&A”) rate for the three months ended June 30, 2021 was $3.93 per BOE compared to $6.45 per BOE for the three months ended June 30, 2020. 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 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 three months ended June 30, 2021, 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, 2021 and 2020:

 

    Three months ended
June 30,
    Change  
    2021     2020     Amount     Percent  
    (in thousands)  
Compensation and benefits, including directors’ fees   $ 410     $ 296     $ 114       39 %
Professional fees, insurance and other     402       71       331       466 %
                                 
Total   $ 812     $ 367     $ 445       121 %

 

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General and administrative expenses increased by $445 thousand during the three-month period ended June 30, 2021, as compared to the prior year period. The increase was primarily attributable to an increase in professional fees of $331 thousand. Professional fees incurred during the three months ended June 30, 2021 related to accounting and tax work, adding additional engineering and accounting contractors and legal fees related to the arbitration of an employment claim. See Note 9 Commitments, Contingencies and Related Party Transactions-Arbitration of Employment Claim in the Notes to the condensed consolidated financial statements included in Part I, Item 1 of this report. Compensation and benefits, including director fees increased $39 thousand from the comparable period in 2020 due to the hiring in April 2021 of a new Vice President of Operations.

 

Non-Operating Income (Expense). Presented below is a comparison of our non-operating income (expense) for the three months ended June 30, 2021 and 2020:

 

    Three months ended
June 30,
    Change  
    2021     2020     Amount     Percent  
    (in thousands)  
Loss on real estate held for sale   $ -     $ (1,054 )   $ 1,054       100 %
Commodity derivative loss     (317 )     -       (317 )     (100 )%
Gain (loss) on marketable equity securities     23       (46 )     69       150 %
Warrant revaluation loss     (4 )     (114 )     110       96 %
Rental property gain (loss), net     6       (18 )     24       133 %
Other     1       -       1       100 %
Interest, net     (6 )     (2 )     (4 )     (200 )%
                                 
Total other income (expense)   $ (297 )   $ (1,234 )   $ 937       76 %

 

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 $1,054 thousand loss to record the value of the building at $725 thousand and land at $250 thousand, representing the amount we expect to realize for the sale of the property. See Note 3Real Estate Held for Sale in the Notes to the condensed consolidated financial statements included in Part I, Item 1 of this report.

 

For the three months ended June 30, 2021, we recognized a loss on our fixed-price swap commodity derivative contract of $317 thousand. In March 2021, we entered into the swap contract to fix the price of 100 barrels of crude oil at $61.90 per barrel through December 31, 2021. The fixed-price swap contract represented approximately 28% of our oil production for the three months ended June 30, 2021. The loss is related to a change in the fair value of the fixed-price swap contract due to the increase in the price of crude oil during the period. See Note 8 Commodity Derivative in the Notes to the condensed consolidated financial statements included in Part I, Item 1 of this report.

 

For the three months ended June 30, 2021, we recognized an unrealized gain on marketable equity securities of $23 thousand as compared to a loss of $46 thousand for the comparable period of 2020. The unrealized gain represents the increase in value of our investment in Anfield Energy Inc. See Note 15. Fair Value Measurements—Marketable Equity Securities in the Notes to the condensed consolidated financial statements included in Part I, Item 1 of this report.

 

For the three months ended June 30, 2021, we recognized a warrant revaluation loss of $4 thousand as compared to a loss of $114 thousand during the three months ending June 30, 2020. The loss for the three months ended June 30, 2021 was attributable to an increase in the value of our common stock during the period, which was partially offset by a decrease in the warrant liability due to the exercise of warrants to purchase 50,000 shares of common stock (leaving warrants to purchase 50,000 shares of common stock outstanding), which occurred in the third fiscal quarter of 2020.

 

For the three months ending June 30, 2021, we recognized a gain on rental property. The gain represents rental income in excess of rental expenses related to our Riverton, Wyoming office building, which is classified as held for sale at June 30, 2021.

 

Interest, net represents the interest expense on short-term financing of insurance premiums for certain policies.

 

Comparison of our Statements of Operations for the Six Months Ended June 30, 2021 and 2020

 

During the six months ended June 30, 2021, we recorded a net loss of $369 thousand as compared to a net loss of $3,957 thousand for the six months ended June 30, 2020. In the following sections we discuss our revenue, operating expenses and non-operating income for the six months ended June 30, 2021, compared to the six months ended June 30, 2020.

 

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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, 2021 and 2020 (in thousands, except average sales prices and production quantities):

 

    Six months ended
June 30,
    Change  
    2021     2020     Amount     Percent  
                         
Revenue:                                
Oil   $ 2,639     $ 1,056     $ 1,583       150 %
Gas     228       56       172       307 %
                                 
Total   $ 2,867     $ 1,112     $ 1,755       158 %
                                 
Production quantities:                                
Oil (Bbls)     45,949       32,014       13,935       44 %
Gas (Mcfe)     72,173       53,437       18,736       35 %
BOE     57,978       40,920       17,058       42 %
BOE per day    

320

     

225

     

95

         
                                 
Average sales prices:                                
Oil (Bbls)   $ 57.43     $ 32.99     $ 24.44       74 %
Gas (Mcfe)     3.16       1.04       2.12       204 %
BOE   $ 49.44     $ 27.17     $ 22.27       82 %

 

The increase in our oil and gas revenue of $1,755 thousand for the six months ended June 30, 2021 as compared to the six months ended June 30, 2020 was due primarily to an increase in oil production of 44% and an increase in the realized price received for our oil production of 74%. The increase in oil prices is primarily due to stronger demand for crude oil on a global basis as the world recovered from government mandated lockdowns which began in mid-March 2020, to reduce the spread of COVID-19. The increase in oil production volumes is primarily the result of the acquisitions of properties we completed during 2020, and our efforts in the first six months of 2021 to return idle wells to production. During the six months ended June 30, 2021, we produced 16,875 Bbls of oil from properties acquired in the second half of 2020.

 

For the six months ended June 30, 2021, we produced 57,978 BOE, or an average of 320 BOE per day, as compared to 40,920 BOE or 225 BOE per day during the comparable period in 2020. This increase was mainly attributable to the acquisition of properties in the last half of 2020 and the return to production of idle wells during the six months ended June 30, 2021. In addition, during the six months ended June 30, 2020, certain North Dakota operators temporarily shut-in production in response to low commodity prices.

 

Oil and Gas Production Costs. Presented below is a comparison of our oil and gas production costs for the six months ended June 30, 2021 and 2020 (dollars in thousands):

 

    Six months ended
June 30,
    Change  
    2021     2020     Amount     Percent  
                         
Production taxes   $ 210     $ 80     $ 130       163 %
Lease operating expense     1,045       742       303       41 %
                                 
Total   $ 1,255     $ 822     $ 433       53 %

 

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For the six months ended June 30, 2021, production taxes increased by $130 thousand, or 163%, as compared to the comparable period in 2020. This increase was primarily attributable to the increase in oil revenues, which increased by 150% compared to 2020. During the six months ended June 30, 2021, lease operating expenses increased by $303 thousand when compared to the six months ended June 30, 2020 as a result of the acquisition of properties during the second half of 2020.

 

Depreciation, Depletion and Amortization. Our DD&A rate for the six months ended June 30, 2021 was $3.88 per BOE compared to $4.76 per BOE for the six months ended June 30, 2020. 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, 2021 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, 2021 and 2020 (dollars in thousands):

 

    Six months ended
June 30,
    Change  
    2021     2020     Amount     Percent  
                         
Compensation and benefits, including directors   $ 749     $ 519     $ 230       44 %
Professional fees, insurance and other