UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

[X]X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended December 31, 2017September 30, 2020

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 No. 1-31785

MEXCO ENERGY CORPORATION

(Exact name of registrant as specified in its charter)

(432) 682-1119

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months and (2) has been subject to such filing requirements for the past 90 days. YES [X] NO [  ]

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 229.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes [X] No [  ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company as defined in Rule 12b-2 of the Exchange Act.

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

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

The number of shares outstanding of the registrant’s common stock, par value $.50 per share, as of February 12, 2018November 5, 2020 was 2,037,266.2,051,866.

MEXCO ENERGY CORPORATION AND SUBSIDIARIES

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

Mexco Energy Corporation and Subsidiaries

CONSOLIDATED BALANCE SHEETS

The accompanying notes are an integral part of the consolidated financial statements.

Mexco Energy Corporation and Subsidiaries

CONSOLIDATED BALANCE SHEETSSTATEMENTS OF OPERATIONS

(Unaudited)

The accompanying notes are an integral part of

the consolidated financial statements.

Mexco Energy Corporation and Subsidiaries

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

The accompanying notes are an integral part of

the consolidated financial statements.

Mexco Energy Corporation and Subsidiaries

CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY

(Unaudited)

The accompanying notes are an integral part of

the consolidated financial statements.

Mexco Energy Corporation and Subsidiaries

CONSOLIDATED STATEMENTS OF CASH FLOWS

For the NineSix Months Ended December 31,September 30,

(Unaudited)

The accompanying notes are an integral part of

the consolidated financial statements.

Mexco Energy Corporation and Subsidiaries

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Nature of Operations

Mexco Energy Corporation (a Colorado corporation) and its wholly owned subsidiaries, Forman Energy Corporation (a New York corporation), Southwest Texas Disposal Corporation (a Texas corporation) and TBO Oil & Gas, LLC (a Texas limited liability company) (collectively, the “Company”) are engaged in the exploration, development and production of natural gas, crude oil, condensate and natural gas liquids (“NGLs”). Most of the Company’s oil and gas interests are centered in the West Texas;Texas and Southeastern New Mexico; however, the Company owns producing properties and undeveloped acreage in thirteenfourteen states. AlthoughAll of the Company’s oil and gas interests predominately are operated by others,others.

Recent Events

The outbreak of the novel coronavirus (“COVID-19”) in the first calendar quarter of 2020 and its continued spread across the globe in the second and third calendar quarters of 2020 has resulted, and is likely to continue to result, in significant economic disruption and has, and is likely to continue to, adversely affect the operations of the Company’s business, as the significantly reduced global and national economic activity has resulted in reduced demand for oil and natural gas. Federal, state and local governments mobilized to implement containment mechanisms to minimize impacts to their populations and economies. Various containment measures, which include the quarantining of cities, regions and countries, while aiding in the prevention of further outbreak, have resulted in a severe drop in general economic activity and a resulting decrease in energy demand. In addition, the global economy has experienced a significant disruption to global supply chains. The extent of the COVID-19 outbreak on the Company’s operational and financial performance will continue to depend on certain developments, including the duration and spread of the outbreak and its continued impact on customer activity and third-party providers. The direct impact to the Company’s operations began to take effect at the close of the fiscal year ended March 31, 2020, and continued through the issuance of these condensed consolidated financial statements. The full extent to which the COVID-19 outbreak may affect the Company’s financial conditions, results of operations or liquidity subsequent to the issuance of these condensed consolidated financial statements is uncertain. At the time of this filing, cases of COVID-19 in the U.S. remain high, including in Texas, where we conduct significant operations.

The severe drop in economic activity, travel restrictions and other restrictions due to COVID-19 have had a significant negative impact on the demand for oil and gas. Due to the significantly reduced demand for oil and natural gas as a result of the COVID-19 pandemic and the current oversupply of oil and natural gas in the market, available storage and capacity for the Company’s customers’ production may be limited or completely unavailable in the future, which may further negatively impact the price of oil. The Company operates five wells in which it ownscannot predict whether, or when, the global supply and demand imbalance will be resolved or whether, or when, oil and natural gas production and economic activities will return to normalized levels. In the absence of additional reductions to global production, oil, natural gas and NGLs prices could remain at current levels, or decline further, for an interest.extended period of time.

2. Basis of Presentation and Significant Accounting Policies

Principles of Consolidation. The consolidated financial statements include the accounts of Mexco Energy Corporation and its wholly owned subsidiaries. All significant intercompany balances and transactions associated with the consolidated operations have been eliminated.

Estimates and Assumptions. In preparing financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”), management is required to make informed judgments, estimates and assumptions that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. In addition, significant estimates are used in determining proved oil and gas reserves. Although management believes its estimates and assumptions are reasonable, actual results may differ materially from those estimates. The estimate of the Company’s oil and natural gas reserves, which is used to compute depreciation, depletion, amortization and impairment of oil and gas properties, is the most significant of the estimates and assumptions that affect these reported results.

Interim Financial Statements.In the opinion of management, the accompanying unaudited consolidated financial statements contain all adjustments (including(consisting only of normal recurring accruals) necessary to present fairly the financial position of the Company as of December 31, 2017,September 30, 2020, and the results of its operations and cash flows for the interim periods ended December 31, 2017September 30, 2020 and 2016.2019. The consolidated financial statements as of December 31, 2017September 30, 2020 and for the three and ninesix month periods ended December 31, 2017September 30, 2020 and 20162019 are unaudited. The consolidated balance sheet as of March 31, 20172020 was derived from the audited balance sheet filed in the Company’s 20172020 annual report on Form 10-K filed with the Securities and Exchange Commission (“SEC”). The results of operations for the periods presented are not necessarily indicative of the results to be expected for a full year. The accounting policies followed by the Company are set forth in more detail in Note 2 of the “Notes to Consolidated Financial Statements” in the Form 10-K. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted in this Form 10-Q pursuant to the rules and regulations of the SEC. However, the disclosures herein are adequate to make the information presented not misleading. It is suggested that these financial statements be read in conjunction with the consolidated financial statements and notes thereto included in the Form 10-K.

Reclassifications.Investments. Certain amountsThe Company accounts for investments of less than 1% in prior periods’limited liability companies using the cost method. The cost of the investment is recorded as an asset on the consolidated balance sheets and when income from the investment is received, it is immediately recognized on the consolidated statements of operations.

Derivative Financial Instruments. The Company’s derivative financial instruments are used to manage commodity price risk attributable to expected oil and gas production. While there is risk the financial benefit of rising oil and gas prices may not be captured, the Company believes the benefits of stable and predictable cash flows outweigh the potential risks.

The Company accounts for derivative financial instruments using fair value accounting and recognizes gains and losses in earnings during the period in which they occur. Unsettled derivative instruments are recorded in the accompanying consolidated balance sheets as either a current or non-current asset or a liability measured at its fair value. The Company only offsets derivative assets and liabilities for arrangements with the same counterparty when right of setoff exists. Derivative assets and liabilities with different counterparties are recorded gross in the consolidated balance sheets. Derivative contract settlements are reflected in operating activities in the accompanying consolidated statements of cash flows.

The Company uses certain pricing models to determine the fair value of its derivative financial instruments. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties. Company management validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming that those securities trade in active markets.

Recent Accounting Pronouncements. In December 2019, the FASB issued ASU No. 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes” (“ASU 2019-12”), which simplifies various aspects of the income tax accounting guidance in ASC 740, including requirements related to the following: (i) hybrid tax regimes; (ii) the tax basis step-up in goodwill obtained in a transaction that is not a business combination; (iii) separate financial statements of entities not subject to tax; (iv) the intraperiod tax allocation exception to the incremental approach; (v) ownership changes in investments - changes from a subsidiary to an equity method investment (and vice versa); (vi) interim-period accounting for enacted changes in tax laws; and (vii) the year-to-date loss limitation in interim-period tax accounting. ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, and interim periods within those fiscal years and early adoption is permitted. If an entity early adopts these amendments in an interim period, it should reflect any adjustments as of the beginning of the annual period that includes that interim period. In addition, an entity that elects to early adopt ASU 2019-12 is required to adopt all of the amendments in the same period. The Company is currently assessing the effect that ASU 2019-12 will have been reclassified to conform with the current period’s presentation. These reclassifications had no effect on previously reportedits financial position, results of operations retained earnings or net cash flows.and disclosures.

3. Property Sales

In December 2017, the Company received approximately $1.9 million in cash from a sale of joint venture leasehold marginal producing working interests in several thousand acres located in Ward and Midland Counties, Texas. Of these proceeds, approximately $1.518 million was applied to the Company’s bank debt and the balance to the Company’s working capital. Additionally, approximately $200,000 of the purchase price is being held in escrow pending payment of closing costs and resolution of title issues as to a small portion of the sale assets. This amount is reflected in accounts receivable escrow on our consolidated balance sheets.

During the first nine months of fiscal 2018, the Company sold for a total consideration of $460,461, leasehold interests in 137 net acres in the Scoop-Stack areas of Canadian and Grady Counties, Oklahoma. The first of these transactions in which the Company retained its interests in the existing producing wellbores on the acreage was in the amount of $336,730. The second transaction in the amount of $123,731 included the producing wellbores as well as the acreage. Of these proceeds, $410,000 was applied to reduce bank indebtedness and the balance of $50,461 was applied to working capital of the Company.

Subsequently, in January 2018, the Company sold additional leasehold interests in the Scoop-Stack area of Grady County, Oklahoma for $46,000 which the Company used to reduce bank indebtedness. The Company retained its interests in the existing producing wellbore on the acreage.

4. Asset Retirement Obligations

The Company’s asset retirement obligations (“ARO”) relate to the plugging of wells, the removal of facilities and equipment, and site restoration on oil and gas properties. The fair value of a liability for an ARO is recorded in the period in which it is initially incurred, discounted to its present value using the credit adjusted risk-free interest rate, and a corresponding amount capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted each period anduntil the capitalizedliability is settled or the well is sold, at which time the liability is removed. The related asset retirement cost is depreciatedcapitalized as part of the carrying amount of our oil and natural gas properties, using the full cost method.properties. The ARO is included inon the Consolidated Balance Sheetsconsolidated balance sheets with the current portion being included in the accounts payable and other accrued expenses.

The following table provides a rollforward of the AROs for the first ninesix months of fiscal 2018:2021:

5. Credit Facility4. Long Term Debt

TheLong-term debt on the Consolidated Balance Sheets consisted of the following as of the dates indicated:

On December 28, 2018, the Company hasentered into a loan agreement with Bank of America, N.A. (the “Agreement”) with West Texas National Bank (“WTNB”), which provided for a credit facility of $5,570,000$1,000,000 with a maturity date of December 28, 2021. The Agreement has no monthly commitment reductionsreduction and a borrowing base to be evaluated on July 30annually.

On February 28, 2020, the Agreement was amended to increase the credit facility to $2,500,000, extend the maturity date to March 28, 2023 and January 1 of each year or at any additional time in the bank’s discretion. The borrowing base was evaluated on January 26, 2018 and set at $950,000. The borrowing base also resets to the extent the Company sells or otherwise disposes of any of its oil and gas properties as the Company is required to pay 100% of such net proceeds to the lender resulting in a permanent reduction ofincrease the borrowing base unless prior approval by the bank states otherwise.to $1,500,000.

TheUnder the Agreement, was renewed eleven times with the eleventh amendment effective as of March 8, 2017 with a maturity date of November 30, 2020. Under such renewal agreement, interest on the facility accrues at an annuala rate equal to the British Bankers Association London Interbank Offered Rate (“BBA LIBOR”prime rate as quoted in the Wall Street Journal plus one-half of one percent (0.5%) daily floating rate, plus 3.0 percentage points, which was 4.56% on December 31, 2017.daily. Interest on the outstanding amount under the credit agreementAgreement is payable monthly. ThereIn addition, the Company will pay an unused commitment fee in an amount equal to one-half of one percent (0.5%) times the daily average of the unadvanced amount of the commitment. The unused commitment fee is payable quarterly in arrears on the last day of each calendar quarter. As of September 30, 2020, there was no availability of this line of credit at December 31, 2017. $325,000 available on the facility.

No principal payments are anticipated to be required through November 30, 2020. the maturity date of the credit facility, March 28, 2023. Upon closing with WTNB on the original Agreement, the Company paid a .5% loan origination fee in the amount of $5,000 plus legal and recording expenses totaling $34,532, which were deferred over the life of the credit facility. Upon closing the amendment to the Agreement, the Company paid a .1% loan origination fee of $2,500 and an extension fee of $3,125 plus legal and recording expenses totaling $12,266, which were also deferred over the life of the credit facility.

Amounts borrowed under the Agreement are collateralized by the common stock of the Company’s wholly owned subsidiaries and substantially all of the Company’s oil and gas properties.

The Agreement contains customary covenants for credit facilities of this type including limitations on change in control, disposition of assets, mergers and reorganizations. The Company is also obligated to meet certain financial covenants under the Agreement and requires minimumsenior debt to earnings before interest, taxes, depreciation and amortization (“EBITDA”) of $650,000 for eachratios (Senior Debt/EBITDA) less than or equal to 4.00 to 1.00 measured with respect to the four trailing four fiscal quarters and minimum interest coverage ratios (EBITDA/Interest Expense) of 2.00 to 1.00 for each quarter. The Company is in compliance with all covenants as of December 31, 2017 and believes it will remain in compliance for the next fiscal year.September 30, 2020.

In addition, this Agreement prohibits the Company from paying cash dividends on its common stock.stock without written permission of WTNB. The Agreement does grantnot permit the Company permission to enter into hedge agreements however, it is under no obligationcovering crude oil and natural gas prices without prior WTNB approval. The Company obtained written permission prior to do so.entering into the current hedge agreement discussed in Note 7.

The Agreement allows for up to $500,000 of the facility to be used for outstanding letters of credit. As of December 31, 2017, one letter of credit for $50,000, in lieu of plugging bond with the Texas Railroad Commission (“TRRC”) covering the properties the Company operates is outstanding under the facility. This letter of credit renews annually. The Company will pay a fee in an amount equal to 1 percent (1.0%) per annum of the outstanding undrawn amount of each standby letter of credit, payable monthly in arrears, on the basis of the face amount outstanding on the day the fee is calculated.

The balance outstanding on the line of credit as of December 31, 2017September 30, 2020 was $950,000.$1,175,000. The following table is a summary of activity on the Bank of America, N.A.WTNB line of credit for the ninesix months ended December 31, 2017:September 30, 2020:

Subsequently, on October 16, 2020, the Company made a payment of $75,000 on the WTNB line of credit leaving a balance of $1,100,000.

The Company also maintained a Certificate of Deposit Account at WTNB to collateralize one outstanding letter of credit for $25,000 in lieu of a plugging bond with the Texas Railroad Commission covering the properties the Company operated. The operated property was sold effective December 1, 2019 and the letter of credit was cancelled. On April 10, 2020, the Certificate of Deposit Account was terminated and the funds deposited into the Company’s operating account.

5. Leases

The Company leases approximately 4,160 rentable square feet of office space from an unaffiliated third party for our corporate office located in Midland, Texas. This includes 1,021 square feet of office space shared with and reimbursed by our majority shareholder. The lease is a 36 month lease that expires in May 2021 and does not include an option to renew. In June 2020, in exchange for a reduction in rent for the months of June and July 2020, the Company agreed to a 2-month extension to its current lease agreement at the regular monthly rate extending its current lease expiration date to July 2021.

The Company determines an arrangement is a lease at inception. Operating leases are recorded in operating lease right-of-use asset, operating lease liability, current, and operating lease liability, long-term on the consolidated balance sheets.

Operating lease right-of-use assets represent the Company’s right to use an underlying asset for the lease term and lease liabilities represent its obligation to make lease payments arising from the lease. Operating lease assets and liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. As the Company’s lease does not provide an implicit rate, the Company uses the incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. The incremental borrowing rate used at adoption was 6.0%. Significant judgement is required when determining the incremental borrowing rate. The Company chose not to discount because the difference is not significant. Rent expense for lease payments is recognized on a straight-line basis over the lease term.

The balance outstanding on the linesheets classification of creditlease assets and liabilities was as follows:

Future minimum lease payments as of February 12, 2018September 30, 2020 under non-cancellable operating leases are as follows:

Net cash paid for our operating lease for the six months ended September 30, 2020 and 2019 was $900,000.$21,693 and $24,173, respectively. Rent expense, less sublease income of $9,459 and $8,080, respectively, is included in general and administrative expenses.

6. Income TaxesFair Value Measurements

On December 22, 2017,The Company applies FASB ASC Topic 820, Fair Value Measurements and Disclosure (“ASC Topic 820”), which establishes a framework for measuring fair value based upon inputs that market participants use in pricing an asset or liability, which are classified into two catagories: observable inputs or unobservable inputs. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company’s own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. These two types of inputs are further prioritized into the tax legislation referred to asfollowing fair value input hierarchy:

Level 1: Quoted prices for identical instruments in active markets at the “Tax Cutsmeasurement date.

Level 2: Quoted prices for similar instruments in active markets; quoted prices for identical or similar instruments in markets that are not active; and Jobs Act” (the 2017 Tax Reform Act) was enacted. Themodel-derived valuations in which all significant inputs and significant value drivers are observable in active markets at the measurement date and for the anticipated term of the instrument.

Level 3: Valuations derived from valuation techniques in which one or more significant changesinputs or significant value drivers are unobservable inputs that impactreflect the reporting entity’s own assumptions about the assumptions market participants would use in pricing the asset or liability acquired, based on the best information available in the circumstances.

The carrying amount reported in the accompanying consolidated balance sheets for cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the immediate or short-term maturity of these financial instruments.

The fair value amount reported in the accompanying consolidated balance sheets for long-term debt approximates fair value because the actual interest rates do not significantly differ from current rates offered for instruments with similar characteristics. See the Company’s note 4 on Long Term Debt for further discussion.

Fair Value Measurements on a Recurring Basis

A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement.

The Company’s commodity derivative instruments were carried at fair value on a recurring basis in the Company’s consolidated balance sheets. The Company uses certain pricing models to determine the fair value of its derivative financial instruments. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties.

Company management validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming that those securities trade in active markets. Assumed credit risk adjustments, based on published credit ratings and public bond yield spreads are applied to the Company’s commodity derivatives. The Company’s derivative instruments are subject to netting arrangements and qualify for net presentation in the consolidated balance sheets in those instances where such arrangements exist with the respective counterparty.

To ensure these derivative instruments are recorded at fair value, valuation adjustments may be required to reflect the creditworthiness of either party as well as market constraints on liquidity. Any such adjustment was not material as of September 30, 2020.

Fair Value Measurements on a Nonrecurring Basis

The asset retirement obligation estimates are derived from historical costs and management’s expectation of future cost environments and, therefore, the Company has designated these liabilities as Level 3 measurements. The significant inputs to this fair value measurement include estimates of plugging, abandonment and remediation costs, well life, inflation and credit-adjusted risk-free rate. See Note 3 for a reconciliation of the beginning and ending balances of the liability for the Company’s asset retirement obligations.

7. Derivative Financial Instruments

It is the Company’s policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive.

The Company is exposed to certain risks relating to its ongoing business operations, such as commodity price risk. Derivative contracts are utilized to economically hedge the reductionCompany’s exposure to price fluctuations and reduce the variability in the corporate federal income tax rate from 35%Company’s cash flows associated with anticipated sales of future oil and natural gas production. The Company follows FASB ASC Topic 815, Derivatives and Hedging (ASC Topic 815), to 21%. Under GAAP,account for its derivative financial instruments.

The Company’s crude oil derivative positions consist of put options. The Company has elected not to designate any of its derivative contracts for hedge accounting. Accordingly, the tax effects of aCompany records the net change in tax law mustthe mark-to-market valuation of these derivative contracts, as well as all payments and receipts on settled derivative contracts, in net realized and unrealized gain (loss) on commodity price hedging contracts on the consolidated statements of operations. All derivative contracts are recorded at fair market value and included in the consolidated balance sheets as assets or liabilities.

The Company may have multiple hedge positions that span a several-month time period and result in fair value asset and liability positions. At the end of the reporting periods, those positions are offset to a single fair value asset or liability for each commodity and the netted balance is reflected in the consolidated balance sheets as an asset or liability.

During the quarter ended June 30, 2020 the Company entered into a series of crude oil put option contracts. All of these such contracts expired in July and August 2020.

The following tables summarizes the amounts of the Company’s realized and unrealized losses on derivative contracts in the Company’s consolidated statements of operations for the six months ended September 30, 2020.

8. Stock-based Compensation

The Company recognized stock-based compensation expense of $13,943 and $8,125 in general and administrative expense in the Consolidated Statements of Operations for the three months ended September 30, 2020 and 2019, respectively. Stock-based compensation expense recognized for the six months ended September 30, 2020 and 2019 was $27,948 and $16,250, respectively. The total cost related to non-vested awards not yet recognized at September 30, 2020 totals $141,861 which is expected to be recognized in the period in which the lawover a weighted average of 2.94 years.

The following table is enacted, or the quarter ending December 31, 2017a summary of activity of stock options for the 2017 Tax Reform Act. GAAP also requires deferred income tax assetssix months ended September 30, 2020:

During the six months ended September 30, 2020, stock options covering 1,500 shares were exercised with a total intrinsic value of $135. The Company received proceeds of $9,435 from these exercises. During the six months ended September 30, 2019, no stock options were exercised.

During the six months ended September 30, 2020, 1,000 unvested stock options were forfeited due to the resignation of an employee and liabilities34,200 vested stock options expired unexercised. There were no stock options forfeited or expired during the six months ended September 30, 2019. No forfeiture rate is assumed for stock options granted to be measureddirectors or employees due to the forfeiture rate history of these types of awards.

Outstanding options at the enacted tax rate expectedSeptember 30, 2020 expire between November 2021 and March 2030 and have exercise prices ranging from $3.34 to apply when temporary differences are to be realized or settled. The Company’s deferred income taxes were remeasured based upon the new tax rates which amounted to a $509,863 reduction in deferred tax asset and valuation amount.$7.00.

9. Income Taxes

A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. To assess that likelihood, we use estimates and judgment regarding our future taxable income, and we consider the tax consequences in the jurisdiction where such taxable income is generated, to determine whether a valuation allowance is required. Such evidence can include our current financial position, our results of operations, both actual and forecasted, the reversal of deferred tax liabilities, and tax planning strategies as well as the current and forecasted business economics of our industry.

Based on the material write-downs of the carrying value of our oil and natural gas properties during fiscal 2016, we are in a net deferred tax asset position as of December 31, 2017.September 30, 2020. Our deferred tax asset is $822,425$1,389,101 as of December 31, 2017September 30, 2020 with a valuation amount of $822,425.$1,389,101. We believe it is more likely than not that these deferred tax assets will not be realized. Management assesses the available positive and negative evidence to estimate whether sufficient future taxable income will be generated to permit the use of deferred tax assets. The amount of the deferred tax asset considered realizable, however, could be adjusted if estimates of future taxable income are reduced or increased or if objective negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence such as future expected growth.

7.10. Related Party Transactions

Related party transactions for the Company relate to shared office expenditures in addition to administrative and operating expenses paid on behalf of the principal stockholder. The total billed to and reimbursed by the stockholder for the quarters ended September 30, 2020 and 2019 was $8,219 and $9,842, respectively. The total billed to and reimbursed by the stockholder for the six months ended September 30, 2020 and 2019 was $18,321 and $19,943, respectively. The principal stockholder pays for his share of the lease amount for the shared office space directly to the lessor. Amounts paid by the principal stockholder directly to the lessor for the three months ending September 30, 2020 and 2019 were $3,846 and $3,981, respectively. Amounts paid by the principal stockholder directly to the lessor for the six months ending September 30, 2020 and 2019 were $7,649 and $7,919, respectively.

11. Loss Per Common Share

The Company’s basic net loss per share has been computed based on the weighted average number of common shares outstanding during the period. Diluted net loss per share assumes the exercise of all stock options having exercise prices less than the average market price of the common stock during the period using the treasury stock method and is computed by dividing net loss by the weighted average number of common shares and dilutive potential common shares (stock options) outstanding during the period. In periods where losses are reported, the weighted-average number of common shares outstanding excludes potential common shares, because their inclusion would be anti-dilutive.

The following is a reconciliation of the number of shares used in the calculation of basic net loss per share and diluted net loss per share for the three and ninesix month periods ended December 31, 2017September 30, 2020 and 2016:2019.

Due to a net loss for the for the three and ninesix months ended December 31, 2017 and 2016,September 30, 2020, the weighted average number of common shares outstanding excludes common stock equivalents because their inclusion would be anti-dilutive.

8. Related Party Transactions12. Subsequent Events

Related party transactions forOn October 16, 2020, the Company relatemade a payment of $75,000 on the WTNB line of credit leaving a balance of $1,100,000.

On October 13, 2020, the Company expended $10,200 for its share to shared office expendituresparticipate in addition to administrative and operating expenses paid on behalf2 horizontal wells in the Bone Spring formation of the principal stockholder.Delaware Basin located in Lea County, New Mexico.

On October 9, 2020, stock options covering 10,200 shares were exercised with a total intrinsic value of $12,083. The total billedCompany received proceeds of $69,360 from these exercises.

The Company completed a review and analysis of all events that occurred after the consolidated balance sheet date to determine if any such events must be reported and reimbursed by the stockholder for the three months ended December 31, 2017 and 2016 was $11,873 and $9,565, respectively. The total billedhas determined that there are no other subsequent events to and reimbursed by the stockholder for the nine months ended December 31, 2017 and 2016 was $30,355 and $22,061, respectively.be disclosed.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Unless the context otherwise requires, references to the “Company”, “Mexco”, “we”, “us” or “our” mean Mexco Energy Corporation and its consolidated subsidiaries.

Cautionary Statements Regarding Forward-Looking Statements. Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) contains “forward-looking statements”forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Forward-looking statements include statements regarding our plans, beliefs or current expectations and may be signified by the words “could”, “should”, “expect”, “project”, “estimate”, “believe”, “anticipate”, “intend”, “budget”, “plan”, “forecast”, “predict” and other similar expressions. Forward-looking statements appear throughout this Form 10-Q with respect to, among other things: profitability; planned capital expenditures; estimates of oil and gas production; future project dates; estimates of future oil and gas prices; estimates of oil and gas reserves; our future financial condition or results of operations; and our business strategy and other plans and objectives for future operations. Forward-looking statements involve known and unknown risks and uncertainties that could cause actual results to differ materially from those contained in any forward-looking statement.

While we have made assumptions that we believe are reasonable, the assumptions that support our forward-looking statements are based upon information that is currently available and is subject to change. All forward-looking statements in thethis Form 10-Q are qualified in their entirety by the cautionary statement contained in this section. We do not undertake to update, revise or correct any of the forward-looking information. It is suggested that these financial statements be read in conjunction with the consolidated financial statements and notes thereto included in the Form 10-K.

Liquidity and Capital Resources. Historically, we have funded our operations, acquisitions, exploration and development expenditures from cash generated by operating activities, bank borrowings, sales of non-core properties and issuance of common stock. Our primary financial resource is our base of oil and gas reserves. We pledgehave pledged our producing oil and gas properties to secure our revolving line of credit. We do not have any delivery commitments to provide a fixed and determinable quantity of its oil and gas under any existing contract or agreement.

Due to depressedthe current commodity price environment, we are applying financial discipline to all aspects of our business. In order to meet obligations, we may continue to sell non-core assets.

Our long term strategy is on increasing profit margins while concentrating on obtaining reserves with low cost operations by acquiring and developing oil and gas properties with potential for long-lived production. We focus our efforts on the acquisition of minerals, royalties and working interests and non-operated properties in areas with significant development potential.

For the first ninesix months of fiscal 2018,2021, cash flow from operations was $153,136,$164,237, a 4404% increase52% decrease when compared to the corresponding period of fiscal 2017. Cash2020 as a result of $2,548,135a 25% decrease in crude oil and natural gas sales primarily due to a 41% decrease in crude oil price and a 10% decrease in natural gas price partially offset by a 19% increase in crude oil production and a 17% increase in natural gas production. Net cash of $449,000 was received from the sale of oil and gas properties, cash of $74,744 was received for drilling refunds, cash of $1,950,000 was used to reduce the line of credit, andnet cash of $802,184$566,000 was used for additions to oil and gas properties.properties and cash of $25,000 was used for an investment at cost basis. Accordingly, net cash increased $23,831.$28,297, leaving cash and cash equivalents on hand of $62,678 as of September 30, 2020.

At December 31, 2017,September 30, 2020, we had working capital of $534,037$240,743 compared to working capital of $367,675$186,785 at March 31, 2017,2020, an increase of $166,362 for$53,958 primarily due to the reasons set forth below.

Oil and Natural Gas Properties

In addition to an indeterminate number of wells to be drilled by other operators on Mexco’s royalty interests, theProperty Development. The Company currently expectsplans to participate in the drilling and completion of approximately 3020 horizontal wells at an estimated aggregate cost of approximately $1,200,000 for the fiscal year ending March 31, 2018.2021 of which, $538,000 has already been expended. The operators of these wells include Concho Resources, Inc., Marathon Oil Permian LLC, McElvain Energy, Inc.,Company, Mewbourne Oil Company, XTO Energy, Inc. and others.

As

During the first six months of December 31, 2017,fiscal 2021, Mexco has expended approximately $700,000 for seventeenparticipated in the drilling and completion of these2 horizontal wells in the Wolfcamp formation of the Delaware Basin located in the Delaware Basin.

The first twowestern portion of thesethe Permian Basin in Lea County, New Mexico with aggregate costs of approximately $233,000. These wells began producingwere completed in September at an2020 with initial average rateproduction rates of 2881,224 barrels of oil; 1,308oil, 4,881 barrels of water;water and 332,0003,422,000 cubic feet of gas per day, or 3431,794 barrels of oil equivalent per day. The third well began producing in November at an initial rate of 245 barrels of oil; 1,053 barrels of water; and 247,000 cubic feet of gas per day, or 286 barrels of oil equivalent per day. These wells are in the Yeso/Paddock formations of the Dodd Federal Unit in the Grayburg San Andres Jackson Field of Eddy County, New Mexico and operated by Concho Resources, Inc. Mexco’s working interest in this unitthese wells is .1848%1.2%.

The next threeDuring the second quarter of fiscal 2021, Mexco participated in the drilling of 4 horizontal wells in the Wolfcamp formation of the Delaware Basin located in the western portion of the Permian Basin in Lea County, New Mexico with aggregate costs of approximately $202,000. Mexco’s working interest in these wells were completed in December 2017 and tested at an average rateis 1.2%.

Also during the first quarter of 1,162 barrels of oil; 2,283 barrels of water; and 1,991,000 cubic feet of gas per day, or 1,494 barrels of oil equivalent per day, with an average flowing tubing pressure of 647 pounds per square inch. These wells arefiscal 2021, Mexco expended $99,000 to participate in the Lowerdrilling of 5 horizontal wells in the Upper Avalon formation of the Delaware Basin located in the western portion of the Permian Basin in Lea County, New Mexico. Mexco’s working interest in these wells is .6%.5%.

The remaining elevenCompany also expended $5,000 during the first quarter of fiscal 2021 for its share to participate in 1 horizontal well in the Bone Spring formation of the Delaware Basin located in the western portion of the Permian Basin in Lea County, New Mexico. Mexco’s working interest in this well is .14%.

In addition to the above investments, the Company plans to expend approximately $280,000 for additional completion costs of 22 horizontal wells located in Eddy and Lea Counties, New Mexico which were drilled during fiscal 2020. To date, $97,000 has already been expended. Of these wells, 7 wells were completed during Mexco’s first quarter of fiscal 2021. In August 2020, 4 more of these seventeen wells have been drilledwere completed and are currently producing at an average production rate of 1,160 barrels of oil; 4,400 barrels of water; and 2,166,000 cubic feet of gas per day, or 1,521 barrels of oil equivalent per day. Mexco’s working interest in various stagesthese wells is .69%. Another 2 of completion.these wells were also completed in August 2020 and are currently producing at an average production rate of 2,026 barrels of oil; 2,347 barrels of water; and 2,514,000 cubic feet of gas per day, or 2,445 barrels of oil equivalent per day. Mexco’s interest in these wells is .104%.

During the first nine months of fiscal 2018,

Effective July 1, 2020, the Company sold its interest in the deep rights of a property in Martin County, Texas for a total consideration of $460,461, leasehold interests in 137 net acres in the Scoop-Stack areas of Canadian and Grady Counties, Oklahoma. The first of these transactions in which the Company retained its interests in the existing producing wellbores on the acreage was in the amount of $336,730. The second transaction in the amount of $123,731 included the producing wellbores as well as the acreage. Of these proceeds, $410,000 was applied to reduce bank indebtedness and the balance of $50,461 was applied to working capital of the Company.

Subsequently, in January 2018, the Company sold additional leasehold interests in the Scoop-Stack area of Grady County, Oklahoma for $46,000 which the Company used to reduce bank indebtedness. The Company retained its interests in the existing producing wellbore on the acreage.

In December 2017, the Company received approximately $1.9 million in cash from a sale of joint venture leasehold marginal producing working interests in several thousand acres located in Ward and Midland Counties, Texas. Of these proceeds, approximately $1.518 million was applied to the Company’s bank debt and the balance to the Company’s working capital. Additionally, approximately $200,000 of the purchase price is being held in escrow pending payment of closing costs and resolution of title issues as to a small portion of the sale assets. This amount is reflected in accounts receivable escrow on our consolidated balance sheets.$100,000.

We are participating in other projects and are reviewing projects in which we may participate. The cost of such projects would be funded, to the extent possible, from existing cash balances and cash flow from operationsoperations. The remainder may be funded through borrowings on the credit facility and, if appropriate, sales of non-core properties.

CrudeBeginning in March 2020, crude oil and natural gas prices remaineddecreased significantly depressed during the last year. Lower product prices reduce our cash flow from operations and diminish the present value of our oil and gas reserves. Lower product prices also offer us less incentive to assume the drilling risks that are inherent in our business.through May 2020. The volatility of the energy markets makes it extremely difficult to predict future oil and natural gas price movements with any certainty. For example, in the last twelve months, theNYMEX West Texas Intermediate (“WTI”) posted price for crude oil has ranged from a low of $39.00on March 31, 2020 was $16.75 per bbl in June 2017 to a high of $56.75and averaged $14.68 and $24.67 per bbl in December 2017.for the months of April and May, respectively. The WTI posted price for crude oil was $36.25 on September 30, 2020. The Henry Hub Spot Market Price (“Henry Hub”) posted price for natural gas has ranged from a low of $2.44on March 31, 2020 was $1.71 per MMBtu in February 2017 to a high of $3.71and averaged $1.74 and $1.75 per MMBtu in January 2017. On December 31, 2017for the WTI posted price for crude oil was $56.75 per bblmonths of April and theMay, respectively. The Henry Hub spotposted price for natural gas was $3.69 per MMBtu.$1.66 on September 30, 2020. See Results of Operations below for realized prices which are substantially below the Henry Hub Spot Market Price.

Paycheck Protection Program (PPP) Loan. On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act commonly referred to as the CARES Act became effective. One component of the CARES Act was the paycheck protection program (“PPP”) which provides small businesses with the resources needed to maintain their payroll and cover applicable overhead. The PPP is implemented by the United States Small Business Administration (“SBA”) with support from the Department of the Treasury. The PPP provides funds to pay up to 24 weeks of payroll costs including benefits. Funds can also be used to pay interest on mortgages, rent, and utilities. The Company applied for, and was accepted to participate in this program. On May 5, 2020, the Company received funding for approximately $68,600.

The loan is a two-year loan with a maturity date of May 5, 2022. The loan bears an annual interest rate of 1%. The loan shall be payable monthly with the first six monthly payments deferred. The Company’s has applied for loan forgiveness under the provisions of Section 1106 of the CARES Act. Loan forgiveness is subject to the sole approval of the SBA. The Company is eligible for loan forgiveness in an amount equal to payments made during the 24-week period beginning on the Loan date, with the exception that no more than 40.0% of the amount of loan forgiveness may be for expenses other than payroll expenses. The Company used all loan proceeds to partially subsidize direct payroll expenses and rent for our corporate office space.

Contractual Obligations.We have no off-balance sheet debt or unrecorded obligations and have not guaranteed the debt of any other party. The following table summarizes our future payments we are obligated to make based on agreements in place as of December 31, 2017:September 30, 2020:

Results of Operations – Three Months Ended December 31, 2017 and 2016.September 30, 2020 Compared to Three Months Ended September 30, 2019. ForThere was a net loss of $41,970 for the quarter ended December 31, 2017, the net loss of $101,228September 30, 2020 compared to a net loss of $159,741$82,787 for the quarter ended December 31, 2016September 30, 2019. This was a result of an increase in oiloperating revenues and gas revenues partially offset by an increasea decrease in total operating expenses asthat is further explained below.

Oil and gas salessales.. Revenue from oil and gas sales was $641,468$629,964 for the thirdsecond quarter of fiscal 2018, an 11%2021, a 1% increase from $580,419$625,750 for the same period of fiscal 2017.2020. This resulted from an increase in oil and gas production and an increase in gas prices partially offset by a decrease in oil prices.

Production and gas production.exploration. Production costs were $217,117 for the second quarter of fiscal 2021, a 5% decrease from $229,042 for the same period of fiscal 2020. This is primarily the result of a decrease in production was primarilylease operating expenses due to the sale of our marginal operated oil and gas properties in PecosEctor County, Texas and to a lesser extent, the shut-in of current production in certain fields with drilling and completion activities. The following table sets forth our oil and gas revenues, production quantities and average prices received during the three months ended December 31, 2017 and 2016:

Production and exploration.Production costs were $248,865 for the third quarter of fiscal 2018, a 6% increase from $234,372 for the same period of fiscal 2017. This increase is primarily the result of an increase in lease operating expense for well repairs on non-operated properties and an increasedecrease in production taxes due toas a result of the increasedecrease in oil and gas sales.

Depreciation, depletion and amortization. Depreciation, depletion and amortization expense was $247,801$236,134 for the thirdsecond quarter of fiscal 2018,2021, a 10% decrease13% increase from $273,885$209,729 for the same period of fiscal 2017,2020, primarily due to a decrease in oil and gas production and the full cost pool as a result of oil and gas property sales. And additionally due to an increase in oil and gas production and a decrease oil and gas reserves partially offset by an increasea decrease in future development costs.the full cost pool amortization base.

General and administrative expenses.General and administrative expenses were $225,528$192,360 for the thirdsecond quarter of fiscal 2018,2021, a 13% increase25% decrease from $199,995$255,294 for the same period of fiscal 2017.2020. This was primarily due to an increase in engineering services, accounting fees, and salaries partially offset by a decrease in stock option compensation expensesalaries, legal fees and insurance expense.

Interest expense.Interest expense was $25,360$13,515 for the thirdsecond quarter of fiscal 2018,2021, a 22% decrease59% increase from $32,378$8,495 for the same period of fiscal 2017,2020, due to a decreasean increase in borrowings partially offset by an increasea decrease in interest rate.rates.

Income taxes.There was no income tax expense for the quarterthree months ended December 31, 2017September 30, 2020 and for the quarterthree months ended December 31, 2016.September 30, 2019. The effective tax rate for the three months ended December 31, 2017September 30, 2020 and December 31, 2016September 30, 2019 was 0%. We are in a net deferred tax asset position and believe it is more likely than not that these deferred tax assets will not be realized.

Results of Operations – NineSix Months Ended December 31, 2017 and 2016.September 30, 2020 Compared to Six Months Ended September 30, 2019. For the ninesix months ended December 31, 2017, theSeptember 30, 2020, there was a net loss of $585,950$341,640 compared to a net loss of $691,099$136,973 for the ninesix months ended December 31, 2016September 30, 2019. This was a result of an increasea decrease in operating revenues partially offset by an increasea decrease in total operating expenses asthat is further explained below.

Oil and gas salessales.. Revenue from oil and gas sales was $1,903,361$994,143 for the ninesix months ended December 31, 2017,September 30, 2020, a 14% increase25% decrease from $1,662,985$1,317,444 for the same period of fiscal 2017.2020. This resulted from an increasea decrease in oil and gas prices partially offset by a decreasean increase in oil and gas production. This decrease in production was primarily due to the sale of our operated oil and gas properties in Pecos County, Texas and to a lesser extent, the shut-in of current production in certain fields with drilling and completion activities. The following table sets forth our oil and gas revenues, production quantities and average prices received during the nine months ended December 31, 2017 and 2016:

Other operating revenue.Other operating revenue was $38,342 for the nine months ended December 31, 2017 compared to $178,174 for the nine months ended December 31, 2016 due to the settlement of a lawsuit for underpayment of royalties from Chesapeake Energy Corporation and Total E & P USA in the amount of $148,614 during fiscal 2017.

Production and exploration.Production costs were $813,570$388,783 for the ninesix months ended December 31, 2017,September 30, 2020, a 13% increasedecrease from $721,864$448,437 for the ninesix months ended December 31, 2016.September 30, 2019. This wasdecrease is primarily the result of an increasea decrease in production taxes as a result of a decrease in oil revenues and a decrease in lease operating expenses and production taxes due to numerous wells being shut-in during the increase inmonth of May 2020 as well as cost cutting measures being implemented by the operators because of the depressed oil and gas revenue.prices.

Depreciation, depletion and amortization. Depreciation, depletion and amortization expense was $844,566$460,239 for the ninesix months ended December 31, 2017,September 30, 2020, a 4% decrease10% increase from $879,637$419,967 for the ninesix months ended December 31, 2016, primarily due to a decrease in oil and gas production and the full cost pool as a result of oil and gas property sales. And additionallySeptember 30, 2019, due to an increase in oil and gas production and a decrease of oil and gas reserves partially offset by an increasea decrease in future development costs.the full cost pool amortization base.

General and administrative expenses.General and administrative expenses were $765,056$441,238 for the ninesix months ended December 31, 2017,September 30, 2020, a 2%22% decrease from $780,608$566,355 for the ninesix months ended December 31, 2016.September 30, 2019. This was primarily due to our efforts to apply financial discipline in all areas of our business resulting in a decrease in salaries, engineering services, insurance expense, legal fees and stock option compensation expense partially offset by an increase in accounting fees and salaries.fees.

Interest expense.Interest expense was $79,310$24,570 for the ninesix months ended December 31, 2017,September 30, 2020, a 36% decrease65% increase from $123,385$14,851 for the nine months ended December 31, 2016same period fiscal 2020 due to a decreasean increase in borrowings partially offset by an increasea decrease in interest rate.

Income taxes.There was no income tax expense for the ninesix months ended December 31, 2017September 30, 2020 and for the ninesix months ended December 31, 2016.September 30, 2019. The effective tax rate for the ninesix months ended December 31, 2017September 30, 2020 and December 31, 2016September 30, 2019 was 0%. We are in a net deferred tax asset position and believe it is more likely than not that these deferred tax assets will not be realized.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

The primary sources of market risk for us include fluctuations in commodity prices and interest rates. All of our financial instruments are for purposes other than trading.

Interest Rate Risk. At December 31, 2017,September 30, 2020, we had an outstanding loan balance of $950,000$1,175,000 under our revolving credit agreement, which bears interest at an annuala rate equal to the BBA LIBOR dailyprime rate as quoted in the Wall Street Journal plus one-half of one percent (0.5%) floating rate, plus 3.0 percentage points.daily. If the interest rate on our bank debt increases or decreases by one percentage point our annual pretax income would change by $9,500$11,750 based on the outstanding balance at December 31, 2017.September 30, 2020.

Credit Risk. Credit risk is the risk of loss as a result of nonperformance by other parties of their contractual obligations. At December 31, 2017, our largest credit risk was $200,000 or 32% of our total accounts receivables which related to escrow pending payment of closing costs on our property sale in Midland and Ward Counties, Texas. Our primary credit risk is related to oil and gas production sold to various purchasers and the receivables are generally not collateralized. At December 31, 2017,September 30, 2020, our largest credit risk associated with any single purchaser was $68,330$212,549 or 17%66% of our total oil and gas receivables. We are also exposed to credit risk in the event of nonperformance from any of our working interest co-owners. At December 31, 2017, our largest credit risk associated with any working interest partner was $8,718 or 29% of our total trade receivables. We have not experienced any significant credit losses.

Energy Price Risk.Risk. Our most significant market risk is the pricing for crude oil and natural gas and crude oil.gas. Our financial condition, results of operations, and capital resources are highly dependent upon the prevailing market prices of, and demand for, oil and natural gas. Prices for oil and natural gas fluctuate widely. We cannot predict future oil and natural gas prices with any certainty. Historically, the marketsPricing for oil and natural gas haveproduction has been volatile and they are likelyunpredictable for several years, and we expect this volatility to continue to be volatile.in the future.

Factors that can cause price fluctuations include the level of global demand for petroleum products, foreign and domestic supply of oil and gas, the establishment of and compliance with production quotas by oil-exporting countries, weather conditions, the price and availability of alternative fuels and overall political and economic conditions in oil producing countries.

Oil prices dropped sharply in early March 2020, and then continued to decline reaching levels below zero dollars per barrel. This was a result of multiple factors affecting supply and demand in global oil and gas markets, including the announcement of price reductions and production increases by OPEC members and other oil exporting nations and the ongoing COVID-19 pandemic. Oil and natural gas prices are expected to continue to be volatile as a result of the changes in oil and natural gas production, inventories and demand, as well as national and international economic performance. Even though oil prices improved in June 2020, we cannot predict when oil prices will stabilize.

Declines in oil and natural gas prices will materially adversely affect our financial condition, liquidity, ability to obtain financing and operating results. Changes in oil and gas prices impact both estimated future net revenue and the estimated quantity of proved reserves. Any reduction in reserves, including reductions due to price fluctuations, can reduce the borrowing base under our revolving credit facility and adversely affect the amount of cash flow available for capital expenditures and our ability to obtain additional capital for our acquisition, exploration and development activities. In addition, a noncash write-down of our oil and gas properties could be required under full cost accounting rules if prices declined significantly, even if it is only for a short period of time. Lower prices may also reduce the amount of crude oil and natural gas that can be produced economically. Thus, we may experience material increases or decreases in reserve quantities solely as a result of price changes and not as a result of drilling or well performance.

Similarly, any improvements in oil and gas prices can have a favorable impact on our financial condition, results of operations and capital resources. Oil and natural gas prices do not necessarily fluctuate in direct relationship to each other. Our financial results are more sensitive to movements in oil prices than gas prices because most of our production is oil. If the average oil price had increased or decreased by ten dollars per barrel for the first ninesix months of fiscal 2018,2021, our pretax income or loss would have changedincreased or decreased by $261,780.$246,770. If the average gas price had increased or decreased by one dollar per mcf for the first ninesix months of fiscal 2018,2021, our pretax income or loss would have changedincreased or decreased by $250,049.$168,406.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures.We maintain disclosure controls and procedures to ensure that the information we must disclose in our filings with the SEC is recorded, processed, summarized and reported on a timely basis. At the end of the period covered by this report, our principal executive officer and principal financial officer reviewed and evaluated the effectiveness of our disclosure controls and procedures, as defined in Exchange Act Rules 13a-15(f)13a-15(e). Based on such evaluation, such officers concluded that, as of December 31, 2017,September 30, 2020, our disclosure controls and procedures were effective.

Changes in Internal Control over Financial Reporting.No changes in our internal control over financial reporting occurred during the ninesix months ended December 31, 2017September 30, 2020 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1.Legal Proceedings

We may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business. We are not aware of any legal or governmental proceedings against us, or contemplated to be brought against us, under various environmental protection statutes or other regulations to which we are subject.

Item 1A.Risk Factors

There have been no material changes to the information previously disclosed in Item 1A. “Risk Factors” in our 20172020 Annual Report on Form 10-K.

Item 2.Unregistered Sales of Equity Securities and Use of Proceeds

None

Item 3.Defaults Upon Senior Securities

None

Item 4.Mine Safety Disclosures

None

Item 5.Other Information

None

Item 6.Exhibits

SIGNATURES

Pursuant to the requirements of the Securities and Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.