UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

(Mark One)

For the Quarter Ended June 30, 2017

OR

Commission File No. 001-03262

 

COMSTOCK RESOURCES, INC.

(Exact name of registrant as specified in its charter)

 

 

5300 Town and Country Blvd., Suite 500, Frisco, Texas 75034

(Address of principal executive offices)

Telephone No.: (972) 668-8800

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes  ☒    No  ☐

Indicate by check mark whether the registrant has submitted electronically 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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes  ☒    No  ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer", "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one):

 

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes  ☐    No  ☒

The number of shares outstanding of the registrant's common stock, par value $0.50, as of August 7, 2017 was 15,478,775.

 

 

 

 

 

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COMSTOCK RESOURCES, INC.

QUARTERLY REPORT

For the Quarter Ended June 30, 2017

INDEX

 

 

 

 

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PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

 

 

 

 

 

 

 

 

 

 

The accompanying notes are an integral part of these statements.

 

 

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COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

The accompanying notes are an integral part of these statements.

 

 

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COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF STOCKHOLDERS' DEFICIT

For the Six Months Ended June 30, 2017

(Unaudited)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

The accompanying notes are an integral part of these statements.

 

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COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

 

 

 

 

 

 

 

 

 

The accompanying notes are an integral part of these statements.

 

 

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COMSTOCK RESOURCES, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2017

(Unaudited)

 

 

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES —

Basis of Presentation

In management's opinion, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly the financial position of Comstock Resources, Inc. and subsidiaries ("Comstock" or the "Company") as of June 30, 2017, the related results of operations for the three months and six months ended June 30, 2017 and 2016, and cash flows for the six months ended June 30, 2017 and 2016.  Net loss and comprehensive loss are the same in all periods presented.   All adjustments are of a normal recurring nature unless otherwise disclosed. Included in the operating results for the six months ended June 30, 2017 is an adjustment reducing interest expense by $2.9 million recorded in the first quarter of 2017 related to the amortization of the discount on long-term debt to correct the calculation of interest expense under the effective interest method.  This amount, which is being accounted for as correction of an accounting error, relates to the period from September 6, 2016 through December 31, 2016.  The Company believes the error is immaterial to the consolidated financial statements for the year ended December 31, 2016, the three months ended September 30, 2016 and the three months ended December 31, 2016.

The accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States have been omitted pursuant to those rules and regulations, although Comstock believes that the disclosures made are adequate to make the information presented not misleading. These unaudited consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in Comstock's Annual Report on Form 10-K for the year ended December 31, 2016.

The results of operations for the three months and six months ended June 30, 2017 are not necessarily an indication of the results expected for the full year.

These unaudited consolidated financial statements include the accounts of Comstock and its wholly-owned subsidiaries.

On July 29, 2016, the Company effected a one-for-five (1:5) reverse split of its outstanding shares of common stock. All amounts disclosed in these financial statements have been adjusted to give effect to this reverse stock split in all periods.

Property and Equipment

The Company follows the successful efforts method of accounting for its oil and gas properties. Costs incurred to acquire oil and gas leasehold are capitalized.

In January 2017, the Company entered an agreement to jointly develop certain acreage prospective for the Haynesville shale in Louisiana and Texas with USG Properties Haynesville, LLC ("USG").  As of June 30, 2017, USG has acquired 6,382 net acres prospective for Haynesville shale development for the joint development program.  The Company operates wells drilled on USG's acreage and has the right to acquire a 25% working interest in the acreage by reimbursing USG for the attributable acreage costs of the wells being drilled.    Comstock received $80,000 for each well drilled as consideration for the Company's services managing the drilling program in addition to customary operating fees.  Comstock and USG plan to continue to acquire additional acreage for the joint development venture.

In January 2016, the Company designated certain of its natural gas properties located in South Texas as held for sale and recognized an impairment charge of $20.8 million in the six months ended June 30, 2016 to adjust the carrying value of these assets to their estimated net realizable value. The sale of these properties was completed in December 2016.

In January 2016, the Company exchanged certain oil and gas properties with another operator in a non-monetary exchange.  Under the exchange, the Company received acreage in DeSoto Parish, Louisiana, prospective for the Haynesville shale, including four producing wells (3.5 net).  The Company exchanged acreage in Atascosa County, Texas, including seven producing wells (5.3 net) for the Haynesville shale properties.  The Company recognized a gain of $0.7 million on this transaction which is included in the loss on sale of oil and gas properties for the six months ended June 30, 2016. The Company also sold certain other oil and gas properties during the first six months of 2016 for total proceeds of $2.1 million. The Company recognized a loss of $1.6 million on these divestitures. 

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Results of operations for the properties that were sold or held for sale were as follows:

 

 

 

Unproved oil and gas properties are periodically assessed and any impairment in value is charged to exploration expense. The costs of unproved properties which are determined to be productive are transferred to oil and gas properties and amortized on an equivalent unit-of-production basis. The Company recognized an impairment included in exploration expense of $7.8 million in the six months ended June 30, 2016 related to leases that were expiring on certain of its unproved oil and gas properties.    

The Company also assesses the need for an impairment of the capitalized costs for its proved oil and gas properties on a property basis.  Accordingly, the Company recognized additional impairments of its oil and gas properties of $1.7 million and $3.7 million for the three months and six months ended June 30, 2016, respectively, to reduce the carrying value of certain properties to their estimated fair value.   

The Company determines the fair values of its oil and gas properties using a discounted cash flow model and proved and risk adjusted probable oil and natural gas reserves.  Undrilled acreage can also be valued based on sales transactions in comparable areas.  Significant Level 3 assumptions associated with the calculation of discounted future cash flows included in the cash flow model include management's outlook for oil and natural gas prices, production costs, capital expenditures, and future production as well as estimated proved oil and gas reserves and risk-adjusted probable oil and natural gas reserves.  Management's oil and natural gas price outlook is developed based on third-party longer-term price forecasts as of each measurement date.  The expected future net cash flows are discounted using an appropriate discount rate in determining a property's fair value.

It is reasonably possible that the Company's estimates of undiscounted future net cash flows attributable to its oil and gas properties may change in the future.  The primary factors that may affect estimates of future cash flows include future adjustments, both positive and negative, to proved and appropriate risk-adjusted probable oil and gas reserves, results of future drilling activities, future prices for oil and natural gas, and increases or decreases in production and capital costs.  As a result of these changes, there may be further impairments in the carrying values of these or other properties.

Accrued Expenses

Accrued expenses at June 30, 2017 and December 31, 2016 consist of the following:

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Reserve for Future Abandonment Costs

Comstock's asset retirement obligations relate to future plugging and abandonment expenses on its oil and gas properties and related facilities disposal. The following table summarizes the changes in Comstock's total estimated liability for such obligations during the six months ended June 30, 2017 and 2016:

Derivative Financial Instruments and Hedging Activities

Comstock periodically uses swaps, floors and collars to hedge oil and natural gas prices and interest rates. Swaps are settled monthly based on differences between the prices specified in the instruments and the settlement prices of futures contracts. Generally, when the applicable settlement price is less than the price specified in the contract, Comstock receives a settlement from the counterparty based on the difference multiplied by the volume or amounts hedged. Similarly, when the applicable settlement price exceeds the price specified in the contract, Comstock pays the counterparty based on the difference.  Comstock generally receives a settlement from the counterparty for floors when the applicable settlement price is less than the price specified in the contract, which is based on the difference multiplied by the volumes hedged. For collars, generally Comstock receives a settlement from the counterparty when the settlement price is below the floor and pays a settlement to the counterparty when the settlement price exceeds the cap. No settlement occurs when the settlement price falls between the floor and cap. All of the Company's derivative financial instruments are used for risk management purposes and, by policy, none are held for trading or speculative purposes. Comstock minimizes credit risk to counterparties of its derivative financial instruments through formal credit policies, monitoring procedures, and diversification. The Company is not required to provide any credit support to its counterparties other than cross collateralization with the assets securing its bank credit facility. None of the Company's derivative financial instruments involve payment or receipt of premiums.  The Company classifies the fair value amounts of derivative financial instruments as net current or noncurrent assets or liabilities, whichever the case may be, by commodity and counterparty.

The Company had the following outstanding derivative financial instruments used for oil and natural gas price risk management at June 30, 2017:

None of the Company's derivative contracts were designated as cash flow hedges. The Company recognized cash settlements and changes in the fair value of its derivative financial instruments as a single component of other income (expenses). The Company recognized gains of $5.3 million and $18 thousand in the three months ended June 30, 2017 and 2016, respectively, and $13.2 million and $0.7 million in the six months ended June 30, 2017 and 2016, respectively, related to the change in fair value of its natural gas swap agreements.     

Stock-Based Compensation

Comstock accounts for employee stock-based compensation under the fair value method. Compensation cost is measured at the grant date based on the fair value of the award and is recognized over the award vesting period. The Company recognized $1.5 million and $1.2 million of stock-based compensation expense within general and administrative expenses related to awards of restricted stock and performance stock units ("PSUs") to its employees and directors in the three months ended June 30, 2017 and 2016, respectively. For the six months ended June 30, 2017 and 2016, the Company recognized $2.8 million and $2.5 million, respectively, of stock-based compensation expense within general and administrative expenses.  

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During the six months ended June 30, 2017, the Company granted 500,002 shares of restricted stock with a grant date fair value of $5.6 million, or $11.11 per share, to its employees and directors. The fair value of each restricted share on the date of grant was equal to its market price. As of June 30, 2017, Comstock had 688,998 shares of unvested restricted stock outstanding at a weighted average grant date fair value of $11.50 per share. Total unrecognized compensation cost related to unvested restricted stock grants of $6.5 million as of June 30, 2017 is expected to be recognized over a period of 2.0 years.

During the six months ended June 30, 2017, the Company granted 241,814 PSUs with a grant date fair value of $4.4 million, or $18.17 per unit, to its employees. As of June 30, 2017, Comstock had 313,248 PSUs outstanding at a weighted average grant date fair value of $17.12 per unit. The number of shares of common stock to be issued related to the PSUs is based on the Company's stock price performance as compared to its peers which could result in the issuance of anywhere from zero to 626,496 shares of common stock. Total unrecognized compensation cost related to these grants of $4.6 million as of June 30, 2017 is expected to be recognized over a period of 2.4 years.  

Income Taxes

Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates. The deferred tax provision in the first three months and six months of 2017 related to adjustments to the valuation allowances on state net operating loss carryforwards.  The deferred income tax provision for the first three months and six months of 2016 related to an increase in the Company's deferred income tax liability resulting from certain state tax law changes enacted during the period. In recording deferred income tax assets, the Company considers whether it is more likely than not that some portion or all of its deferred income tax assets will be realized in the future.  The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those deferred income tax assets would be deductible.  The Company believes that after considering all the available objective evidence, historical and prospective, with greater weight given to historical evidence, management is not able to determine that it is more likely than not that all of its deferred tax assets will be realized.  As a result, the Company established valuation allowances for its deferred tax assets and U.S. federal and state net operating loss carryforwards that are not expected to be utilized due to the uncertainty of generating taxable income prior to the expiration of the carryforward periods.   

The following is an analysis of consolidated income tax expense:

The difference between the Company's effective tax rate and the 35% federal statutory rate is caused by valuation allowances on deferred taxes and state taxes. The impact of these items varies based upon the Company's projected full year loss and the jurisdictions that are expected to generate the projected losses. The difference between the federal statutory rate of 35% and the effective tax rate on the income (loss) before income taxes is due to the following:

 

 

 

 

 

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The Company's federal income tax returns for the years subsequent to December 31, 2012, remain subject to examination. The Company's income tax returns in major state income tax jurisdictions remain subject to examination for various periods subsequent to December 31, 2011. The Company currently believes that all other significant filing positions are highly certain and that all of its other significant income tax positions and deductions would be sustained under audit or the final resolution would not have a material effect on the consolidated financial statements. Therefore, the Company has not established any significant reserves for uncertain tax positions.

Future use of the Company's federal and state net operating loss carryforwards may be limited in the event that a cumulative change in the ownership of Comstock's common stock by more than 50% occurs within a three-year period.  Such a change in ownership could result in a substantial portion of the Company's net operating loss carryforwards being eliminated or becoming restricted. It is highly likely that a change in ownership that would result from the future conversion of the Company's convertible notes would result in limits on the future use of its net operating loss carryforwards.   

Fair Value Measurements

The Company holds or has held certain items that are required to be measured at fair value.  These include cash and cash equivalents held in bank accounts and derivative financial instruments in the form of oil and natural gas price swap agreements. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. A three-level hierarchy is followed for disclosure to show the extent and level of judgment used to estimate fair value measurements:

Level 1 — Inputs used to measure fair value are unadjusted quoted prices that are available in active markets for the identical assets or liabilities as of the reporting date.

Level 2 — Inputs used to measure fair value, other than quoted prices included in Level 1, are either directly or indirectly observable as of the reporting date through correlation with market data, including quoted prices for similar assets and liabilities in active markets and quoted prices in markets that are not active. Level 2 also includes assets and liabilities that are valued using models or other pricing methodologies that do not require significant judgment since the input assumptions used in the models, such as interest rates and volatility factors, are corroborated by readily observable data from actively quoted markets for substantially the full term of the financial instrument.

Level 3 — Inputs used to measure fair value are unobservable inputs that are supported by little or no market activity and reflect the use of significant management judgment. These values are generally determined using pricing models for which the assumptions utilize management's estimates of market participant assumptions.

The Company's valuation of cash and cash equivalents is a Level 1 measurement. The Company's natural gas price swap agreements are not traded on a public exchange. Their value is determined utilizing a discounted cash flow model based on inputs that are readily available in public markets and, accordingly, the valuation of these swap agreements is categorized as a Level 2 measurement.

The following table summarizes financial assets accounted for at fair value as of June 30, 2017:

 

As of June 30, 2017, the Company's other financial instruments, comprised solely of its fixed rate debt, had a carrying value of $1.1 billion and a fair value of $1.1 billion.  The fair market value of the Company's fixed rate debt was based on quoted prices as of June 30, 2017, a Level 2 measurement.

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Earnings Per Share

Basic earnings per share is determined without the effect of any outstanding potentially dilutive securities and diluted earnings per share is determined with the effect of any outstanding securities that are potentially dilutive. Unvested share-based payment awards containing nonforfeitable rights to dividends are considered to be participating securities and included in the computation of basic and diluted earnings per share pursuant to the two-class method. PSUs represent the right to receive a number of shares of the Company's common stock that may range from zero to up to two times the number of PSUs granted on the award date based on the achievement of certain performance measures during a performance period. The number of potentially dilutive shares related to PSUs is based on the number of shares, if any, which would be issuable at the end of the respective period, assuming that date was the end of the contingency period. Common stock warrants represent the right to convert the warrants into common stock at an exercise price of $0.01 per share.  The treasury stock method is used to measure the dilutive effect of outstanding PSUs and common stock warrants.  The shares that would be issuable upon exercise of the conversion rights contained in the Company's convertible debt for each period are based on the if-converted method for computing potentially dilutive shares of common stock that could be issued upon conversion.

Basic and diluted loss per share for the three months and six months ended June 30, 2017 and 2016 were determined as follows:

 

 

 

 

At June 30, 2017 and December 31, 2016, 688,998 and 354,986 shares of restricted stock, respectively, are included in common stock outstanding as such shares have a nonforfeitable right to participate in any dividends that might be declared and have the right to vote on matters submitted to the Company's stockholders. Weighted average shares of unvested restricted stock outstanding during the three months and six months ended June 30, 2017 and 2016 were as follows:

 

 

For the three months ended June 30, 2017 and 2016, all stock options, unvested PSUs, common stock warrants and contingently issuable shares related to the convertible debt were anti-dilutive to earnings and excluded from weighted average shares used in the computation of earnings per share in all periods presented due to the net loss in those periods.  Options to purchase common stock, warrants exercisable into common stock, PSUs that were outstanding and contingently issuable shares related to the convertible debt that were excluded as anti-dilutive from the determination of diluted earnings per share are as follows:

 

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Supplementary Information With Respect to the Consolidated Statements of Cash Flows

For the purpose of the consolidated statements of cash flows, the Company considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.

Cash payments made for interest and income taxes for the six months ended June 30, 2017 and 2016, respectively, were as follows:

 Interest of $18.6 million related to the Company's convertible notes was paid in-kind during the six months ended June 30, 2017.

Recent Accounting Pronouncements

In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014-09, Revenue from Contracts with Customers (Topic 606) ("ASU 2014-09"), which supersedes nearly all existing revenue recognition guidance under existing generally accepted accounting principles.  This new standard is based upon the principal that revenue is recognized to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. ASU 2014-09 is effective for annual and interim periods beginning after December 15, 2017. Early adoption is permitted beginning with periods after December 15, 2016 and entities have the option of using either a full retrospective or modified approach to adopt ASU 2014-09. The Company is currently reviewing its primary oil and natural gas marketing agreements in order to assess the impact of adoption.  At this time, adopting this standard is not expected to have a material impact on the Company's financial statements because recognition of revenue is not expected to materially change under the new standard, since most of the Company's revenue will continue to be recognized as production is delivered.  However, the Company is still evaluating the ultimate impact of this accounting standard on its consolidated results of operations, financial position, cash flows and financial disclosures.  This evaluation will continue throughout 2017, and the Company is currently planning to adopt this new standard in the first quarter of 2018.  The Company has not yet determined which method of adoption it will apply for this new standard.

In February 2016, the FASB issued ASU No. 2016-02, Leases ("ASU 2016-02").  ASU 2016-02 requires lessees to include most leases on their balance sheets, but recognize lease costs in their financial statements in a manner similar to accounting for leases prior to ASC 2016-02.  ASU 2016-02 is effective for annual periods ending after December 15, 2018 and interim period thereafter.  Early adoption is permitted.  The Company is currently evaluating the new guidance and anticipates that certain operating leases that it has in place will be reflected as an asset and a liability in its consolidated balance sheet.  The Company has not yet determined which method of adoption it will apply for this new standard.

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(2) LONG-TERM DEBT –

At June 30, 2017, long-term debt was comprised of the following:

Interest on the 10% Senior Secured Toggle Notes is payable on March 15 and September 15 and the notes mature on March 15, 2020.  The Company has the option to pay up to $75.0 million of accrued interest by issuing additional notes. To the extent that interest is paid in kind, the interest rate increases to 12¼% only for that interest payment and would result in up to an additional $91.9 million of notes outstanding.

Interest on the 7¾% Convertible Second Lien PIK Notes is payable on April 1 and October 1 and these notes mature on April 1, 2019.  Interest on the 9½% Convertible Second Lien PIK Notes is payable on June 15 and December 15 and these notes mature on June 15, 2020.  Interest on the convertible notes is only payable in kind.  Each series of the convertible notes is convertible, at the option of the holder, into 81.2 shares of the Company's common stock for each $1,000 of principal amount of notes.  The convertible notes will mandatorily convert into shares of common stock following a 15 consecutive trading day period during which the daily volume weighted average price of the Company's common stock is equal to or greater than $12.32 per share.  $9.9 million of principal amount of the convertible notes plus accrued interest thereon were converted into 826,327 shares of common stock during the six months ended June 30, 2017.

During the six months ended June 30, 2016, the Company retired $87.5 million in principal amount of the 2019 Notes and $19.8 million of the 2020 Notes in exchange in the aggregate for the issuance of 2,748,403 shares of common stock and $3.5 million in cash.  A gain of $89.6 million was recognized on the exchanges and purchases of the 2019 Notes and the 2020 Notes during the six months ended June 30, 2016.  The gain is included in the net gain on extinguishment of debt for the difference between the market value of the stock on the closing date of the exchange and the net carrying value of the debt and the related net premium and net debt issuance costs.

Comstock has a $50.0 million revolving credit facility with Bank of Montreal and Bank of America, N.A. that matures March 4, 2019. As of June 30, 2017, the Company did not have any borrowings outstanding under the revolving credit facility. Indebtedness under the revolving credit facility is guaranteed by all of the Company's subsidiaries and is secured by substantially all of Comstock's and its subsidiaries' assets.  Borrowings under the revolving credit facility bear interest, at Comstock's option, at either (1) LIBOR plus 2.5% or (2) the base rate (which is the higher of the administrative agent's prime rate, the federal funds rate plus 0.5% or 30 day LIBOR plus 1.0%) plus 1.5%. A commitment fee of 0.5% per annum is payable quarterly on the unused credit line.  The revolving credit facility contains covenants that, among other things, restrict the payment of cash dividends and repurchases of common stock, limit the amount of additional debt that Comstock may incur and limit the Company's ability to make certain loans, investments and divestitures. The only financial covenants are the maintenance of a current ratio, including availability under the revolving credit facility, of at least 1.0 to 1.0 and the maintenance of an asset coverage ratio of proved developed reserves to amounts outstanding under the revolving credit facility of at least 2.5 to 1.0. The Company was in compliance with these covenants as of June 30, 2017.

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All of the Company's subsidiaries guarantee the bank credit facility, the 10% Senior Secured Toggle Notes, the 7¾% Convertible Second Lien PIK Notes, the 9½% Convertible Second Lien PIK Notes, and the other outstanding senior notes.  The bank credit facility, the 10% Senior Secured Toggle Notes and the convertible notes are secured by liens on substantially all of the assets of the Company and its subsidiaries.  The allocation of proceeds related to the liens on the Company's assets are governed by intercreditor agreements granting priority to the bank credit facility.  Proceeds from liens on the convertible notes are also subject to the priority of the 10% Senior Secured Toggle Notes.  

(3) STOCKHOLDERS' EQUITY –

At June 30, 2017 the Company had warrants outstanding to purchase 415,087 shares of common stock at an exercise price of $0.01 per share.  Warrants for 246,793 shares of common stock were exercised during the six months ended June 30, 2017, respectively.  

(4) Commitments and Contingencies –

From time to time, Comstock is involved in certain litigation that arises in the normal course of its operations. The Company records a loss contingency for these matters when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated. The Company does not believe the resolution of these matters will have a material effect on the Company's financial position or results of operations.

The Company has entered into natural gas transportation and treating agreements through July 2019. Maximum commitments under these transportation agreements as of June 30, 2017 totaled $3.3 million.  As of June 30, 2017, the Company had commitments for contracted drilling services through April 2018 of $9.9 million.

 

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ITEM 2: MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

This report contains forward-looking statements that involve risks and uncertainties that are made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Actual results may differ materially from those anticipated in our forward-looking statements due to many factors. The following discussion should be read in conjunction with the consolidated financial statements and notes thereto included in this report and in our annual report filed on Form 10-K for the year ended December 31, 2016.

Results of Operations

 

 

Revenues –

Our oil and natural gas sales grew 51% in the second quarter of 2017 to $61.5 million from $40.7 million in the second quarter of 2016, primarily due to the increase in our natural gas production driven by our Haynesville shale drilling program and higher oil and natural gas prices. Natural gas sales in the second quarter increased 96% to $50.4 million due to higher natural gas prices and production growth.  Our natural gas production increased by 28% and our realized natural gas price increased by 53% as compared to the second quarter of 2016.  Oil sales in the second quarter of 2017 decreased by 26% to $11.0 million from the second quarter of

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2016 due to a 32% decrease in our oil production which was offset in part by a 7% increase in oil prices.  The decline in oil production is attributable to the lack of drilling activity in our Eagle Ford shale properties in South Texas.

In the first six months of 2017, our oil and natural gas sales increased by $38.4 million (50%) to $115.3 million from $76.9 million in the first six months of 2016. Natural gas sales in the first six months of 2017 increased by $40.5 million (80%) from 2016 while oil sales decreased by $2.1 million (8%) from 2016. Our natural gas production increased by 15% from 2016 and our realized natural gas price increased by 57%. The decrease in oil sales is attributable to the 34% decline in our production which was partially offset by the 40% increase in realized oil prices.

We utilize oil and natural gas price swaps to manage our exposure to oil and natural gas prices and protect returns on investment from our drilling activities.  Gains related to our natural gas derivative financial instruments were $5.3 million and $18,000 for the three months ended June 30, 2017 and 2016, respectively, and $13.2 million and $0.7 million for the six months ended June 30, 2017 and 2016, respectively.  The following table presents our natural gas prices before and after the effect of cash settlements of our derivative financial instruments:

 

Costs and Expenses —

Our production taxes decreased $0.2 million to $1.1 million for the first quarter of 2017 from $1.3 million in the second quarter of 2016 despite the increase in sales. Production taxes of $2.2 million for the first six months of 2017 decreased $0.3 million as compared with production taxes of $2.5 million for the first six months of 2016. The decrease is mainly due to our lower oil sales. Much of the increase in natural gas sales is attributable to new wells drilled which are initially exempt from production taxes.

Gathering and transportation costs for the first quarter of 2017 decreased $0.5 million to $3.5 million as compared to $4.0 million in the second quarter of 2016. Gathering and transportation costs for the first six months of 2017 decreased $0.7 million to $7.7 million as compared to $8.4 million for the first six months of 2016. Our gathering and transportation costs have decreased due to lower transportation rates we have negotiated for our natural gas production.

Our lease operating expense of $9.4 million for the first quarter of 2017 decreased $3.6 million (27%) from lease operating expense of $13.0 million for the first quarter of 2016 despite the increase in production. This decrease primarily reflects lower costs associated with our Haynesville shale properties as well as the divestiture of certain high lifting cost properties in 2016.  Our lease operating expense for the first six months of 2017 of $19.3 million decreased $6.6 million or 26% from our lease operating expense of $25.9 million for the first six months of 2016. Our lease operating expense of $0.56 per Mcfe produced for the six months ended June 30, 2017 was $0.25 per Mcfe lower than the lease operating expense of $0.81 per Mcfe for the same period in 2016.  

Exploration costs of $7.8 million in the three months ended March 31, 2016, related to the impairments of certain unevaluated leases.

Depreciation, depletion and amortization (“DD&A”) decreased $5.7 million (16%) to $30.3 million in the second quarter of 2017 from $36.0 million in the second quarter of 2016. Our DD&A per equivalent Mcf produced decreased $0.68 (30%) to $1.60 for the three months ended June 30, 2017 from $2.28 for the three months ended June 30, 2016. DD&A for the first six months of 2017 of $60.2 million decreased by $14.6 million (20%) from DD&A expense of $74.9 million for the six months ended June 30, 2016. For the first six months of 2017, our per unit DD&A rate of $1.74 decreased $0.58 (25%) from our DD&A rate of $2.32 for the first six months of 2016. The lower rates in 2017 reflect the increase in production from our lower cost Haynesville shale properties.

General and administrative expenses, which are reported net of overhead reimbursements, increased to $6.6 million for the first quarter of 2017 from $5.7 million in the first quarter of 2016. Included in general and administrative expenses are stock-based compensation of $1.5 million and $1.2 million for the three months ended June 30, 2017 and 2016, respectively.  For the first six months of 2017, general and administrative expenses of $13.0 million increased $1.8 million (15%) from general and administrative expenses for the six months ended June 30, 2016 of $11.2 million. Included in general and administrative expense is stock-based compensation of $2.8 million and $2.5 million for the six months ended June 30, 2017 and 2016, respectively. The increase in 2017 primarily relates to higher compensation costs for our employees.

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We assess the need for impairment of the capitalized costs for our oil and gas properties on a property basis.  We recognized impairment charges of $1.7 million and $24.5 million on our oil and gas properties during the three months and six months ended June 30, 2016, respectively. Included in impairments for the six months ended June 30, 2016 is an impairment of $20.8 million which reduced the carrying value of our South Texas natural gas properties classified as assets held for sale.  We also had a net loss on sale of oil and gas properties of $1.6 million and $0.9 million for the three months and six months ended June 30, 2016, respectively.

Interest expense increased $7.9 million to $36.8 million for the first quarter of 2017 from interest expense of $28.9 million in the first quarter of 2016. Interest expense increased $10.9 million to $69.7 million for the first six months of 2017 from interest expense of $58.8 million in the first six months of 2016. The increase in interest expense mainly reflects the amortization of the debt discounts recognized as a result of the gain recognized on debt exchange that we completed in September 2016 and the amortization of costs incurred on the exchange.  These increases were partially offset by lower interest expense as a result of the reduction in the principal amount of our debt outstanding due to our debt reduction program in 2016.  

During the six months ended June 30, 2016, we recognized a net gain on extinguishment of debt of $89.6 million due to the retirement of $87.5 million principal of the 2019 Notes and $19.8 million principal of the 2020 Notes as part of our debt reduction program.

Income taxes for the three months ended June 30, 2017 were a provision of $0.5 million as compared to a provision of $88,000 for the three months ended June 30, 2016. Income taxes for the six months ended June 30, 2017 were a provision of $1.0 million as compared to a provision of $4.5 million for the six months ended June 30, 2016. The provisions primarily related to adjustments of the valuation allowances against our federal and state net operating loss carryforwards.  During the first quarter of 2016, Louisiana changed its tax laws with respect to the utilization of net operating losses. As a result of this tax law change we increased our deferred income tax liability related to state income taxes by $4.5 million.  

We reported a net loss of $21.4 million, or $1.45 per share, for the three months ended June 30, 2017 as compared to net income of $4.9 million, or $0.41 per diluted share, for the three months ended June 30, 2016. We reported a net loss of $44.4 million, or $3.06 per share, for the six months ended June 30, 2017, as compared to a net loss of $51.7 million, or $4.82 per share, for the six months ended June 30, 2016. The net loss for the six months ended June 30, 2017 was primarily due to our interest expense, which includes the higher non-cash interest expense recognized in 2017 related to the amortization of discounts and costs recognized on our senior notes exchange.  

Liquidity and Capital Resources

Funding for our activities has historically been provided by our operating cash flow, debt or equity financings or proceeds from asset sales. For the six months ended June 30, 2017, our primary source of funds was operating cash flow and cash on hand.  Cash provided from operating activities for the six months ended June 30, 2017 was $55.5 million as compared to cash used for operating activities of $31.2 million for the first six months of 2016.  This increase in operating cash flow is due to higher oil and gas sales and the reduction in cash interest.

Our primary needs for capital, in addition to funding our ongoing operations, relate to the acquisition, development and exploration of our oil and gas properties and the repayment of our debt. In the first six months of 2017, we incurred capital expenditures of $86.6 million to fund our development and exploration activities.

The following table summarizes our capital expenditure activity, on an accrual basis, for the six months ended June 30, 2017 and 2016:

 

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We expect to fund our ongoing development and exploration activities with future operating cash flow and from cash on hand. The timing of most of our future capital expenditures is discretionary because we have no material long-term capital expenditure commitments. Consequently, we have a significant degree of flexibility to adjust the level of our capital expenditures as circumstances warrant. As of June 30, 2017, we have three drilling rigs under contract through April 2018 at a cost of $9.9 million and commitments of $3.3 million to transport and treat natural gas through July 2019. We also have obligations to incur future payments for dismantlement, abandonment and restoration costs of oil and gas properties which are currently estimated to be incurred primarily after 2022.

Through June 30, 2017, we drilled nine (8.1 net) and completed ten (8.8 net) operated horizontal Haynesville shale wells and one non-operated well.  We are currently planning to drill 18 (9.0 net) additional wells in 2017. Capital expenditures for the remainder of 2017 are estimated at $81.0 million. We may reduce the number of wells we drill this year depending upon the natural gas prices that we realize.

At June 30, 2017 we had outstanding $697.2 million of 10% Senior Secured Toggle Notes due 2020, $273.8 million of 7¾% Convertible Second Lien PIK Notes due 2019 and $178.6 million of 9½% Convertible Second Lien PIK Notes due 2020.  We also had $25.6 million of unsecured notes outstanding due in 2019 and 2020. Interest on the 10% Senior Secured Toggle Notes is payable on March 15 and September 15 and the notes mature on March 15, 2020.  We have the option to pay up to $75.0 million of accrued interest by issuing additional notes.  To the extent that interest is paid in kind, the interest rate increases to 12¼% only for that interest payment and would result in up to an additional $91.9 million of notes outstanding.  Interest on the 7¾% Convertible Second Lien PIK Notes is payable on April 1 and October 1 and these notes mature on April 1, 2019.  Interest on the 9½% Convertible Second Lien PIK Notes is payable on June 15 and December 15 and these notes mature on June 15, 2020.  Interest on the convertible notes is only payable in kind.  Each series of the convertible notes is convertible, at the option of the holder, into 81.2 shares of our common stock for each $1,000 of principal amount of notes.  The convertible notes will mandatorily convert into shares of common stock following a 15 consecutive trading day period during which the daily volume weighted average price of our common stock is equal to or greater than $12.32 per share. $9.9 million of principal amount of the convertible notes plus related accrued interest were converted into 826,327 shares of common stock during the six months ended June 30, 2017.

During the six months ended June 30, 2016, we retired $87.5 million in principal amount of the 2019 Notes and $19.8 million of the 2020 Notes in exchange in the aggregate for the issuance of 2,748,403 shares of common stock and $3.5 million in cash.  A gain of $89.6 million was recognized on the exchanges and purchases of the 2019 Notes and the 2020 Notes during the six months ended June 30, 2016.  The gain is included in the net gain on extinguishment of debt for the difference between the market value of the stock on the closing date of the exchange and the net carrying value of the debt and the related net premium and net debt issuance costs.

We have a $50.0 million revolving credit facility with Bank of Montreal and Bank of America, N.A. that matures March 4, 2019.  As of June 30, 2017, there were no borrowings outstanding under the revolving credit facility.  Indebtedness under the revolving credit facility is guaranteed by all of our subsidiaries and is secured by substantially all of our and its subsidiaries' assets.  Borrowings under the revolving credit facility bear interest, at our option, at either (1) LIBOR plus 2.5% or (2) the base rate (which is the higher of the administrative agent's prime rate, the federal funds rate plus 0.5% or 30 day LIBOR plus 1.0%) plus 1.5%. A commitment fee of 0.5% per annum is payable quarterly on the unused credit line.  The revolving credit facility contains covenants that, among other things, restrict the payment of cash dividends and repurchases of common stock, limit the amount of additional debt that we may incur and limit our ability to make certain loans, investments and divestitures. The only financial covenants are the maintenance of a current ratio, including availability under the revolving credit facility, of at least 1.0 to 1.0 and the maintenance of an asset coverage ratio of proved developed reserves to amounts outstanding under the revolving credit facility of at least 2.5 to 1.0. We were in compliance with these covenants as of June 30, 2017.

All of our subsidiaries guarantee the bank credit facility, the 10% Senior Secured Toggle Notes, the 7¾% Convertible Second Lien PIK Notes, the 9½% Convertible Second Lien PIK Notes, and the other outstanding senior notes.  The bank credit facility, the 10% Senior Secured Toggle Notes and the convertible notes are secured by liens on substantially all of our and our subsidiaries assets.  The allocation of proceeds related to the liens on our assets are governed by intercreditor agreements granting priority to the bank credit facility.  Proceeds from liens on the convertible notes are also subject to the priority of the 10% Senior Secured Toggle Notes.  

Federal Taxation

Future use of our net operating loss carryforwards may be limited in the event that a cumulative change in the ownership of our common stock by more than 50% occurs within a three-year period.  Such a change in ownership could result in a substantial portion of our net operating loss carryforwards being eliminated or becoming restricted. It is highly likely that a change in ownership that would result from the future conversion of our convertible notes would result in limits on the future use of our net operating loss carryforwards.

 

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ITEM 3: QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

Oil and Natural Gas Prices

Our financial condition, results of operations and capital resources are highly dependent upon the prevailing market prices of natural gas and oil. These commodity prices are subject to wide fluctuations and market uncertainties due to a variety of factors, some of which are beyond our control. Factors influencing oil and natural gas prices include the level of global demand for crude oil, the foreign supply of oil and natural gas, the establishment of and compliance with production quotas by oil exporting countries, weather conditions that determine the demand for natural gas, the price and availability of alternative fuels and overall economic conditions. It is impossible to predict future oil and natural gas prices with any degree of certainty. Sustained weakness in natural gas and oil prices may adversely affect our financial condition and results of operations, and may also reduce the amount of oil and natural gas reserves that we can produce economically. Any reduction in our natural gas and oil reserves, including reductions due to price fluctuations, can have an adverse effect on our ability to obtain capital for our exploration and development activities. Similarly, any improvements in natural gas and oil prices can have a favorable impact on our financial condition, results of operations and capital resources.

As of June 30, 2017, we have entered into natural gas price swap agreements to hedge approximately 20.7 billion cubic feet of our 2017 and 2018 production at an average price of $3.38 per Mcf. None of our derivative contracts have margin requirements or collateral provisions that could require funding prior to the scheduled cash settlement date. The change in the fair value of our natural gas swaps that would result from a 10% change in commodities prices at June 30, 2017 would be $3.6 million.  Such a change in fair value could be a gain or a loss depending on whether prices increase or decrease.  

Based on our oil and natural gas production for the six months ended June 30, 2017 and our outstanding natural gas price swap agreements, a $0.10 change in the price per Mcf of natural gas would have changed our cash flow by approximately $1.7 million and a $1.00 change in the price per barrel of oil would have resulted in a change in our cash flow from continuing operations for such period by approximately $0.5 million.

Interest Rates

At June 30, 2017, we had approximately $1.2 billion principal amount of long-term debt outstanding.  All but $25.6 million of this debt is secured by substantially all of our assets.  Of this amount, our first lien notes of $697.2 million bear interest at a fixed rate of 10%, our second lien notes of $273.8 million bear interest at a fixed rate of 7¾% and our second lien notes of $178.6 million bear interest at a fixed rate of 9½%.  At our option, up to $75.0 million of the interest on the first lien debt is payable in-kind.  All of the interest on the second lien debt is payable in kind.  The $25.6 million of unsecured senior notes bear interest at rates of between 7¾% to 10% and mature in 2019 and 2020.  The fair market value of our fixed rate debt as of June 30, 2017 was $1.1 billion based on the market price of approximately 91% of the face amount of such debt.  At June 30, 2017, we did not have any borrowings outstanding under our revolving credit facility, which is subject to variable rates of interest that are tied at our option to either LIBOR or the corporate base rate.

ITEM 4: CONTROLS AND PROCEDURES

As of June 30, 2017, we carried out an evaluation, under the supervision and with the participation of our chief executive officer and chief financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934). Based on this evaluation, our chief executive officer and chief financial officer concluded that our disclosure controls and procedures were effective as of June 30, 2017 to provide reasonable assurance that information required to be disclosed by us in the reports filed or submitted by us under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms, and to provide reasonable assurance that information required to be disclosed by us is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure. There were no changes in our internal controls over financial reporting (as such term is defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) that occurred during the quarter ended June 30, 2017, that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

 

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PART II — OTHER INFORMATION

ITEM 6: EXHIBITS

 

 

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SIGNATURES

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

 

 

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