MEXCO ENERGY CORP - Quarter Report: 2017 September (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2017

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)

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.

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 November 10, 2017 was 2,037,266.

MEXCO ENERGY CORPORATION AND SUBSIDIARIES

Table of Contents

Mexco Energy Corporation and Subsidiaries

CONSOLIDATED BALANCE SHEETS

(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 Six Months Ended 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 West Texas; however, the Company owns producing properties and undeveloped acreage in thirteen states. Although most of the Company’s oil and gas interests are operated by others, the Company operates five wells in which it owns an interest.

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, 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 (consisting only of normal recurring accruals) necessary to present fairly the financial position of the Company as of September 30, 2017, and the results of its operations and cash flows for the interim periods ended September 30, 2017 and 2016. The consolidated financial statements as of September 30, 2017 and for the three and six month periods ended September 30, 2017 and 2016 are unaudited. The consolidated balance sheet as of March 31, 2017 was derived from the audited balance sheet filed in the Company’s 2017 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 financial statements and notes thereto included in the Form 10-K.

3. 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 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, and the capitalized cost is depreciated over the useful life of the related asset. The ARO is included in the Consolidated 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 six months of fiscal 2018:

4. Credit Facility

The Company has a loan agreement with Bank of America, N.A. (the “Agreement”), which provided for a credit facility of $5,570,000 with no monthly commitment reductions and a borrowing base to be evaluated on July 30 and January 1 of each year or at any additional time in the Bank’s discretion. The borrowing base was evaluated on July 31, 2017 and set at $2,525,500. 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 of the borrowing base unless prior approval by Bank states otherwise. As of September 30, 2017, the borrowing base was set at $2,518,000.

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 annual rate equal to the British Bankers Association London Interbank Offered Rate (“BBA LIBOR”) daily floating rate, plus 3.0 percentage points, which was 4.24% on September 30, 2017. Interest on the outstanding amount under the credit agreement is payable monthly. There was no availability of this line of credit at September 30, 2017. No principal payments are anticipated to be required through November 30, 2020. 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 minimum earnings before interest, taxes, depreciation and amortization (“EBITDA”) of $650,000 for each trailing four fiscal quarters and minimum interest coverage ratio (EBITDA/Interest Expense) of 2.00 to 1.00 for each quarter. The Company is in compliance with all covenants as of September 30, 2017 and believes it will remain in compliance for the next fiscal year.

In addition, this Agreement prohibits the Company from paying cash dividends on its common stock. The Agreement does grant the Company permission to enter into hedge agreements however, it is under no obligation to do so.

The amended Agreement allows for up to $500,000 of the facility to be used for outstanding letters of credit. As of September 30, 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 September 30, 2017 was $2,468,000. The following table is a summary of activity on the Bank of America, N.A. line of credit for the six months ended September 30, 2017:

5. 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 September 30, 2017. Our deferred tax asset is $1,333,489 as of September 30, 2017 with a valuation amount of $1,333,489. 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.

6. 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 three months ended September 30, 2017 and 2016 was $9,649 and $6,852, respectively. The total billed to and reimbursed by the stockholder for the six months ended September 30, 2017 and 2016 was $18,481 and $12,495, respectively.

7. 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 and diluted net loss per share for the three and six month periods ended September 30, 2017 and 2016.

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

8. Subsequent Events

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 has determined that there are no subsequent events to 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 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 this 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 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 pledge 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 depressed 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 six months of fiscal 2018, cash flow from operations was $326,435, a 540% increase when compared to the corresponding period of fiscal 2017. Cash of $549,507 was received from the sale of oil and gas properties, cash of $19,500 was refunded for a drilling prepayment, cash of $432,000 was used to reduce the line of credit, cash of $481,005 was used for additions to oil and gas properties and cash of $6,529 was used to settle asset retirement obligations. Accordingly, net cash decreased $17,563.

At September 30, 2017, we had working capital of $57,964 compared to working capital of $367,675 at March 31, 2017, a decrease of $309,711 for the reasons set forth below.

Oil and Natural Gas Property Developments and Transactions

During fiscal 2017, Mexco participated with various percentage interests in seventeen horizontal wells in the Delaware Basin, a sub basin located in the western portion of the Permian Basin in Eddy and Lea Counties, New Mexico with aggregate costs of $723,800 as of September 30, 2017.

During the second quarter of fiscal 2018, the last two of these seventeen wells were completed flowing at an average rate of 1,004 barrels of oil; 1,231 barrels of water; and, 1,363,000 cubic feet of gas per day, or 1,231 barrels of oil equivalent per day, with an average flowing tubing pressure of 768 pounds per square inch, on 48/64 inch chokes. Mexco’s working interests in these two wells is .18%.

In addition to an indeterminate number of wells to be drilled by other operators on Mexco’s royalty interests, the Company currently expects to participate in the drilling and completion of approximately 30 horizontal wells at an estimated aggregate cost of approximately $1,200,000 for the fiscal year ending March 31, 2018. The operators of these wells include Apache Corporation, Bold Energy III, LLC, Concho Resources, Inc., Mewbourne Oil Company, XTO Energy, Inc. and others.

As of September 30, 2017, fourteen of these horizontal wells are in various stages of drilling or completion operations and approximately $486,000 of these costs has been expended. These fourteen wells are also located in the Delaware Basin.

During the first quarter 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.

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, cash flow from operations and sales of non-core properties.

Crude oil and natural gas prices have remained 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. 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, the NYMEX WTI posted price for crude oil has ranged from a low of $39.00 per bbl in June 2017 to a high of $50.75 per bbl in February 2017. The Henry Hub Spot Market Price (“Henry Hub”) for natural gas has ranged from a low of $2.08 per MMBtu in November 2016 to a high of $3.80 per MMBtu in December 2016. On September 30, 2017 the WTI posted price for crude oil was $48.25 per bbl and the Henry Hub spot price for natural gas was $2.94 per MMBtu.

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 September 30, 2017:

Results of Operations – Three Months Ended September 30, 2017 Compared to Three Months Ended September 30, 2016. There was a net loss of $189,170 for the quarter ended September 30, 2017 compared to a net loss of $237,902 for the quarter ended September 30, 2016. This was primarily a result of an increase in oil and gas revenues and a decrease in interest expense partially offset by a decrease in other operating revenue and an increase in operating expenses.

Oil and gas sales. Revenue from oil and gas sales was $610,451 for the second quarter of fiscal 2018, a 12% increase from $546,164 for the same period of fiscal 2017. This resulted from an increase in oil and gas prices partially offset by a decrease in oil and gas production for the three months ended September 30, 2017.

Other operating revenue. Other operating revenue was $8,637 for the three months ended September 30, 2017 compared to $34,678 for the three months ended September 30, 2016 primarily due to the three year note portion of the settlement of a lawsuit for underpayment of royalties paid last year from Chesapeake Energy Corporation and Total E&P USA in the amount of $25,219.

Production and exploration. Production costs were $254,842 for the second quarter of fiscal 2018, a 12% increase from $226,548 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 increase in production taxes due to the increase in oil and gas sales.

Depreciation, depletion and amortization. Depreciation, depletion and amortization expense was $285,507 for the second quarter of fiscal 2018, a 4% decrease from $297,370 for the same period of fiscal 2017, primarily due to a decrease in oil and gas production and an increase in oil and gas reserves partially offset by an increase in future development costs.

General and administrative expenses. General and administrative expenses were $232,869 for the second quarter of fiscal 2018, a 1.5% decrease from $236,367 for the same period of fiscal 2017. This was primarily due to a decrease in legal fees, stock option compensation and insurance costs partially offset by an increase in accounting fees and salary expense.

Interest expense. Interest expense was $26,734 for the second quarter of fiscal 2018, a 46% decrease from $49,573 for the same period of fiscal 2017, due to a decrease in borrowings partially offset by an increase in interest rate.

Income taxes. There was no income tax expense for the three months ended September 30, 2017 and for the three months ended September 30, 2016. The effective tax rate for the three months ended September 30, 2017 and September 30, 2016 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 – Six Months Ended September 30, 2017 Compared to Six Months Ended September 30, 2016. For the six months ended September 30, 2017, there was a net loss of $484,722 compared to a net loss of $531,358 for the six months ended September 30, 2016. This was a result of an increase in operating revenues and a decrease in interest expense partially offset by an increase in total operating expenses.

Oil and gas sales. Revenue from oil and gas sales was $1,261,893 for the six months ended September 30, 2017, a 17% increase from $1,082,567 for the same period of fiscal 2017. This resulted from an increase in oil and gas prices and oil production partially offset by a decrease in gas production for the six months ended September 30, 2017.

Other operating revenue. Other operating revenue was $24,879 for the six months ended September 30, 2017 compared to $168,458 for the six months ended September 30, 2016 primarily due to the settlement of a lawsuit for underpayment of royalties received last year from Chesapeake Energy Corporation and Total E&P USA in the amount of $148,614.

Production and exploration. Production costs were $564,705 for the six months ended September 30, 2017, a 16% increase from $487,492 for the six months ended September 30, 2016. This increase is primarily the result of XTO Energy, Inc. incorrectly providing us a refund for marketing and transportation fees of approximately $67,000 which is being reversed via netting over the next 8-10 months.

Depreciation, depletion and amortization. Depreciation, depletion and amortization expense was $596,765 for the six months ended September 30, 2017, a 1.5% decrease from $605,752 for the six months ended September 30, 2016, due to an increase in oil and gas reserves and a decrease in gas production partially offset by an increase in future development costs.

General and administrative expenses. General and administrative expenses were $539,528 for the six months ended September 30, 2017, a 7% decrease from $580,613 for the six months ended September 30, 2016. This was primarily due to a decrease in engineering and consulting services, insurance expenses and legal fees partially offset by an increase in accounting fees.

Interest expense. Interest expense was $53,950 for the six months ended September 30, 2017, a 41% decrease from $91,007 for the same period fiscal 2017 due to an increase in interest rate partially offset by a decrease in borrowings.

Income taxes. There was no income tax expense for the six months ended September 30, 2017 and for the six months ended September 30, 2016. The effective tax rate for the six months ended September 30, 2017 and September 30, 2016 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 September 30, 2017, we had an outstanding loan balance of $2,468,000 under our revolving credit agreement, which bears interest at an annual rate equal to the BBA LIBOR daily floating rate, plus 3.0 percentage points. If the interest rate on our bank debt increases or decreases by one percentage point our annual pretax income would change by $24,680 based on the outstanding balance at September 30, 2017.

Credit Risk. Credit risk is the risk of loss as a result of nonperformance by other parties of their contractual obligations. Our primary credit risk is related to oil and gas production sold to various purchasers and the receivables are generally not collateralized. At September 30, 2017, our largest credit risk associated with any single purchaser was $111,802 or 36% 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 partners. At September 30, 2017, our largest credit risk associated with any working interest co-owner was $6,947 or 40% of our total trade receivable. We have not experienced any significant credit losses.

Energy Price Risk. Our most significant market risk is the pricing for natural gas and crude oil. 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 markets for oil and gas have been volatile, and they are likely to continue to be volatile.

Factors that can cause price fluctuations include the level of global demand for petroleum products, foreign 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.

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 six months of fiscal 2018, our pretax loss would have changed by $179,690. If the average gas price had increased or decreased by one dollar per mcf for the first six months of fiscal 2018, our pretax loss would have changed by $179,016.

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(e). Based on such evaluation, such officers concluded that, as of September 30, 2017, 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 six months ended September 30, 2017 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 2016 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.