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.

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 RegulationS-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

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

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

The number of shares outstanding of the registrant’s common stock, par value $0.50, as of ~~November 5, 2015~~August 1, 2016 was ~~47,720,176.~~12,504,562.

September 30,
2015


December 31,
2014

(In thousands)

ASSETS

Cash and Cash Equivalents

$
163,840

$
2,071

Accounts Receivable:

Oil and gas sales

19,680

32,849

Joint interest operations

4,084

16,192

Derivative Financial Instruments

1,314

—

Other Current Assets

2,933

10,105

Total current assets

191,851

61,217

Property and Equipment:

Unevaluated oil and gas properties

80,449

201,459

Oil and gas properties, successful efforts method

4,299,265

4,282,088

Other

19,515

19,630

Accumulated depreciation, depletion and amortization

(3,083,879
)

(2,305,008
)
Net property and equipment

1,315,350

2,198,169

Other Assets

22,473

14,951

$
1,529,674

$
2,274,337

LIABILITIES AND STOCKHOLDERS’ EQUITY

Accounts Payable

$
51,213

$
117,329

Accrued Liabilities

39,764

44,842

Total current liabilities

90,977

162,171

Long-term Debt

1,297,312

1,070,445

Deferred Income Taxes

10,981

154,547

Reserve for Future Abandonment Costs

15,106

14,900

Other Non-Current Liabilities

—

2,002

Total liabilities

1,414,376

1,404,065

Commitments and Contingencies

Stockholders’ Equity:

Common stock – $0.50 par, 75,000,000 shares authorized, 47,725,176 and 46,858,415 shares outstanding at September 30, 2015 and December 31, 2014, respectively

23,863

23,429

Additional paid-in capital

483,592

480,434

Accumulated earnings (deficit)

(392,157
)

366,409

Total stockholders’ equity

115,298

870,272


$
1,529,674

$
2,274,337

Three Months Ended September 30,


Nine Months Ended September 30,

2015


2014


2015


2014

Revenues:

(In thousands, except per share amounts)

Oil sales

$
27,706

$
107,899


$
124,783

$
309,283

Natural gas sales

33,654

37,084

80,411

133,332

Total revenues

61,360

144,983

205,194

442,615

Operating expenses:

Production taxes

2,170

6,369

8,951

18,437

Gathering and transportation

3,729

3,125

9,842

10,039

Lease operating

16,687

15,858

49,650

44,899

Exploration

5,040

11,449

70,309

11,449

Depreciation, depletion and amortization

79,445

99,977

261,907

283,390

General and administrative

5,653

7,927

20,795

25,910

Impairment of oil and gas properties

544,714

15

547,101

271

(Gain) loss on sale of oil and gas properties

(52
)

—

111,778

—

Total operating expenses

657,386

144,720

1,080,333

394,395

Operating income (loss)

(596,026
)

263

(875,139
)

48,220

Other income (expenses):

Interest income

138

—

308

—

Net gain on extinguishment of debt

51,054

—

55,586

—

Gain (loss) on derivative financial instruments

1,078

12,033

1,705

(2,763
)
Other income

273

223

746

513

Interest expense

(32,159
)

(14,912
)

(86,720
)

(43,359
)

Total other income (expenses)

20,384

(2,656
)

(28,375
)

(45,609
)

Income (loss) before income taxes

(575,642
)

(2,393
)

(903,514
)

2,611

Benefit from (provision for) income taxes

30,646

490

144,948

(1,451
)
Net income (loss)

$
(544,996
)

$
(1,903
)

$
(758,566
)

$
1,160

Net income (loss) per share:

Basic

$
(11.81
)

$
(0.04
)

$
(16.45
)

$
0.02

Diluted

$
(11.81
)

$
(0.04
)

$
(16.45
)

$
0.02

Dividends per common share

$
—

$
0.125


$
—

$
0.375

Weighted average shares outstanding:

Basic

46,150

46,651

46,100

46,628

Diluted

46,150

46,651

46,100

46,948

Common
Stock
(Shares)


Common
Stock –
Par Value


Additional
Paid-in
Capital


Accumulated Earnings (Deficit)


Total

(In thousands)

Balance at January 1, 2015

46,858

$
23,429

$
480,434

$
366,409

$
870,272

Stock-based compensation

945

473

5,588

—

6,061

Restricted stock used for tax withholdings

(78
)

(39
)

(487
)

—

(526
)
Excess income taxes from stock-based compensation

—

—

(1,943
)

—

(1,943
)
Net loss

—

—

—

(758,566
)

(758,566
)
Balance at September 30, 2015

47,725

$
23,863

$
483,592

$
(392,157
)

$
115,298

Nine Months Ended
September 30,

2015


2014

(In thousands)

Cash Flows from Operating Activities:



Net income (loss)

$
(758,566
)

$
1,160

Adjustments to reconcile net income (loss) to net cash provided by operating activities:



Loss on sale of oil and gas properties

111,778

—

Deferred income taxes

(146,118
)


1,487

Leasehold impairments, dry hole costs and other exploration costs

70,309



11,449

Impairment of oil and gas properties

547,101



271

Depreciation, depletion and amortization

261,907



283,390

(Gain) loss on derivative financial instruments

(1,705
)


2,763

Settlements of derivative financial instruments

391



(5,702
)
Net gain on extinguishment of debt

(55,586
)


—

Amortization of debt discount, premium and issuance costs

3,952



3,140

Stock-based compensation

6,061



7,842

Excess income taxes from stock-based compensation

1,943



1,087

(Increase) decrease in accounts receivable

25,277



(20,257
)
(Increase) decrease in other current assets

7,292



(1,561
)
Increase (decrease) in accounts payable and accrued liabilities

(50,560
)


43,914

Net cash provided by operating activities

23,476



328,983

Cash Flows From Investing Activities:



Capital expenditures

(232,896
)


(502,362
)
Proceeds from asset sales

102,674

—

Net cash used for investing activities

(130,222
)


(502,362
)

Cash Flows from Financing Activities:



Borrowings

790,000



300,750

Principal payments on debt

(502,815
)


(100,000
)
Debt issuance costs

(16,201
)


(2,524
)
Tax withholdings related to restricted stock

(526
)


(2,349
)
Excess income taxes from stock-based compensation

(1,943
)


(1,087
)
Dividends paid

—



(17,945
)
Net cash provided by financing activities

268,515



176,845

Net increase in cash and cash equivalents

161,769



3,466

Cash and cash equivalents, beginning of period

2,071



2,967

Cash and cash equivalents, end of period

$
163,840


$
6,433

In ~~management's~~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"~~(“Comstock” or the ~~"Company"~~“Company”) as of ~~September~~June 30, ~~2015,~~2016, the related results of operations for the three ~~months~~ and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014,~~2015, and cash flows for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014.~~2015. Net ~~income (loss)~~loss and comprehensive ~~income (loss)~~loss are the same in all periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed.

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~~Comstock’s Annual Report on Form 10-K for the year ended December 31, ~~2014.~~2015 and its current report for Form 8-K dated August 1, 2016.

The results of operations for the three ~~months~~ and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 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 and controlled subsidiaries.

On July 19, 2016, the Company announced a one-for-five (1:5) reverse split of its issued and outstanding common stock which became effective on July 29, 2016. All amounts disclosed in these financial statements have been adjusted to give effect to the effect of this reverse stock split in all periods.

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.

At June 30, 2016, the Company reflected certain of its natural gas properties located in South Texas as assets held for sale in the accompanying consolidated balance sheet. The Company engaged financial advisors in February 2016 to sell the properties. At June 30, 2016, these assets were reflected on the balance sheet at $42.5 million, representing their estimated net realizable value on a sale less costs to sell. The Company has recognized an impairment charge of $20.8 million during the six months ended June 30, 2016 to adjust the carrying value of these assets to their net realizable value. The impairment, which is a Level 3 fair value measurement, was computed using a discounted cash flow valuation approach which is consistent with the Company’s methodology for determining impairments of its proved oil and gas properties. The asset retirement obligation related to these properties of $3.4 million is included in accrued liabilities at June 30, 2016. In June 30, 2015, Comstock entered into an agreement to sell certain of its oil and gas properties located in and near Burleson County, Texas to a third party. This sale closed on July 22, 2015 with an effective date of May 1, 2015 and the Company received net proceeds from this sale of $102.5 million in the third quarter of 2015. The Company recognized a loss on this sale of $111.8 million in the three months and six months ended June 30, 2015 operating results.

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

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 3,637 net acres in DeSoto Parish, Louisiana, prospective for the Haynesville shale, including four producing wells (3.5 net). The Company exchanged 2,547 net acres 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 net loss on sales and exchange of oil and gas properties for the six months ended June 30, 2016. The Company also sold certain 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.

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 impairment charges in exploration expense of ~~$5.1~~$23.0 million ~~and $68.6~~ during the three ~~and nine~~ months ended ~~September~~June 30, 2015 and $7.8 million and $63.5 million during the six months ended June 30, 2016 and 2015, respectively, related to certain leases that the Company currently does not plan to develop. ~~There~~No unproved impairments were ~~no impairments of unproved property in~~recognized during the ~~first nine~~three months ~~of 2014.~~

The Company also assesses the need for an impairment of the capitalized costs for its proved oil and gas properties on a property basis. ~~During the three months ended September 30, 2015, reductions~~Reductions to ~~management's~~management’s oil and natural gas price ~~outlook~~outlooks in 2016 and 2015 resulted in indications of impairment of certain of the ~~Company's oil properties in South Texas and certain natural gas properties in Texas and Louisiana.~~Company’s properties. Accordingly, the Company recognized ~~an impairment~~additional impairments of ~~$544.7~~its oil and gas properties of $1.7 million and ~~$547.1~~$2.0 million for the three months ended June 30, 2016 and ~~nine~~2015, respectively, and $3.7 million and $2.4 million for the six months ended ~~September~~June 30, 2016 and 2015, respectively, to reduce the carrying value of these 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 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~~management’s outlook for oil and natural gas prices, production costs, capital expenditures, and future production as well as estimated proved reserves and risk-adjusted probable reserves. ~~Management's~~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~~property’s fair value.

The following table presents the fair value and impairments recorded by the Company during the three months ended September 30, 2015, as well as the average oil price per barrel and gas price per thousand cubic feet over the life of the properties and the applicable discount rates utilized in the Company's assessments:

It is reasonably possible that the ~~Company's~~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 ~~and possible~~ 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, or if in the future the Company does not have access to sufficient capital to develop ~~all of its proved and risk-adjusted probable~~any undrilled reserves used in its assessment, there may be further impairments in the carrying values of these or other properties.

During the three months ended September 30, 2015, the Company completed the sale of certain oil and gas properties located in and near Burleson County, Texas. The Company received net proceeds of $102.7 million and recognized a net loss on sale of $111.8 million. Results of operations for these properties were as follows:

In January 2015, the Company purchased a 20% interest in an airplane that previously had been owned 80% by the Company and 20% by two executive officers of the Company. The purchase price for the 20% interest of $1.7 million was based on the then fair market value of the airplane determined by a third party. This related party transaction was approved by the Company's audit committee and board of directors.

Accrued liabilities at ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014~~2015 consist of the following:

~~Comstock's~~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~~Comstock’s total estimated liability for such obligations during the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

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~~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. All of ~~Comstock's~~Comstock’s derivative financial instruments are with parties that are lenders under its bank credit facility. 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~~Company’s derivative financial instruments involve payment or receipt of premiums.

As of ~~September~~June 30, ~~2015,~~2016, the Company had ~~the following~~no outstanding commodity ~~derivatives:~~derivatives. The Company had derivative financial instruments outstanding on June 30, 2015 that hedged production for the subsequent twelve month

period. None of the ~~Company's~~Company’s derivative contracts ~~have been~~were designated as cash flow hedges. The Company ~~recognizes~~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 ~~a gain~~gains of ~~$1.1 million~~$18,000 and ~~$1.7~~$0.7 million related to the change in fair value of its natural gas swap agreements during the three months and ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, respectively. The Company recognized a gain of $0.6 million related to the change in fair value of its natural gas swap agreements during the three and six months ended June 30, 2015. Cash settlements on the Company’s natural gas derivative financial instruments were receipts of ~~$0.4~~$1.1 million and $2.1 million for the three months and ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, respectively. The Company had ~~gains of $12.0 million and losses of $2.8 million related to its oil swap agreements during the three months and nine months ended September 30, 2014, respectively. Cash~~no cash settlements ~~on oil~~from derivative financial instruments ~~were payments~~in the first six months of $0.4 million and $5.7 million for the three months and nine months ended September 30, 2014, respectively. The estimated fair value and carrying value of the Company's derivative financial instruments was an asset of $1.3 million as of September 30, 2015, and was classified as a current asset. There were no derivative financial instruments outstanding on December 31, 2014.2015.

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. During the three months ended ~~September~~June 30, ~~2015~~2016 and ~~2014,~~2015, the Company recognized ~~$2.1~~$1.2 million and ~~$2.8~~$2.1 million, respectively, of stock-based compensation expense within general and administrative expenses related to awards of restricted stock and performance stock units to its employees and directors. For the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014,~~2015, the Company recognized ~~$6.1~~$2.5 million and ~~$7.8~~$4.0 million, respectively, of stock-based compensation expense within general and administrative expenses.

During the ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, the Company granted ~~1,010,371~~229,618 shares of restricted stock with a grant date fair value of ~~$5.4~~$1.3 million, or ~~$5.34~~$5.45 per share, to its employees. The fair value of each restricted share on the date of grant was equal to its market price. As of ~~September~~June 30, ~~2015,~~2016, Comstock had ~~1,575,302~~354,974 shares of unvested restricted stock outstanding at a weighted average grant date fair value of ~~$9.90~~$15.25 per share. Total unrecognized compensation cost related to unvested restricted stock grants of ~~$6.6~~$4.4 million as of ~~September~~June 30, ~~2015~~2016 is expected to be recognized over a period of ~~1.5~~2.1 years.

During the ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, the Company granted ~~471,249~~60,013 performance share units ~~("PSUs"~~(“PSUs”) with a grant date fair value of ~~$2.1~~$0.4 million, or ~~$4.38~~$7.00 per unit, to its employees. As of ~~September~~June 30, ~~2015,~~2016, Comstock had ~~669,604~~134,627 PSUs outstanding at a weighted average grant date fair value of ~~$9.13~~$22.09 per unit. The number of shares of common stock to be issued related to the PSUs is based on the ~~Company's~~Company’s stock price performance as compared to its peers which could result in the issuance of anywhere from zero to ~~1,400,173~~269,253 shares of common stock. Total unrecognized compensation cost related to these grants of ~~$2.6~~$1.7 million as of ~~September~~June 30, ~~2015~~2016 is expected to be recognized over a period of ~~1.9~~1.7 years.

As of ~~September~~June 30, ~~2015,~~2016, Comstock had outstanding options to purchase ~~102,650~~11,730 shares of common stock at a weighted average exercise price of ~~$32.94~~$166.10 per share. All of the stock options were exercisable and there were no unrecognized compensation costs related to the stock options as of ~~September~~June 30, ~~2015.~~2016. No stock options were granted or exercised during the ~~three months or nine~~six months ended ~~September~~June 30, ~~2015~~2016.

Deferred income taxes are provided to reflect the future tax consequences or ~~2014.~~

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 six months of 2016 related to an increase in the Company’s deferred income tax liability resulting from 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 and, therefore, has ~~established~~recorded a valuation allowance of ~~$178.6~~$17.9 million and ~~$71.6~~$4.9 million against its net federal deferred tax assets and state deferred

tax assets (net of the federal tax benefit), respectively, ~~at September~~during the six months ended June 30, ~~2015.~~2016. The Company will continue to assess the valuation allowance against deferred tax assets considering all available information obtained in future reporting periods.

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 difference between the ~~Company's~~Company’s effective tax rate and the 35% federal statutory rate is caused by ~~non-deductible stock compensation, state~~valuation allowances on deferred taxes and ~~the establishing of a valuation allowance on deferred~~state taxes. The impact of these items varies based upon the ~~Company's~~Company’s projected full year loss and the jurisdictions that are expected to generate the projected losses.

The difference between the ~~Company's~~Company’s customary rate of 35% and the effective tax rate on ~~income (loss)~~the loss before income taxes is due to the following:

Three Months Ended
September 30,


Nine Months Ended
September 30,

2015


2014


2015


2014

Tax at statutory rate

35.0
%

35.0
%


35.0
%

35.0
%
Tax effect of:

State income taxes net of federal benefit

2.0

5.5

2.1

(5.5
)
Nondeductible stock-based compensation

—

(15.1
)

(0.1
)

20.1

Valuation allowance on deferred tax assets – Federal

(31.0
)

—

(19.8
)

—

Valuation allowance on deferred tax asset – State

(0.7
)

—

(1.2
)

—

Other

—

(4.9
)

—

6.0

Effective tax rate

5.3
%

20.5
%

16.0
%

55.6
%

The ~~Company's~~Company’s federal income tax returns for the years subsequent to December 31, 2011, remain subject to examination. The ~~Company's~~Company’s income tax returns in major state income tax jurisdictions remain subject to examination for the year ended December 31, 2008 and for various periods subsequent to December 31, ~~2009.~~2010. A state tax return in one state jurisdiction is currently under review. The Company has evaluated the preliminary findings in this jurisdiction and believes it is more likely than not that the ultimate resolution of these matters will not have a material effect on the ~~Company's~~Company’s financial statements. 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~~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~~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 ~~Comstock's~~Comstock’s net operating loss carryforwards being eliminated or becoming restricted, and the Company may need to recognize an additional valuation allowance reflecting the restricted use of these net operating loss carryforwards in the period when such an ownership change occurred. ~~The~~In October 2015, the Company established a rights plan ~~on October 1, 2015~~ to deter ownership changes that would trigger this ~~limitation (see Note 5).~~limitation.

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~~management’s estimates of market participant assumptions.

The ~~Company's~~Company’s valuation of cash and cash equivalents is a Level 1 measurement. The ~~Company's~~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. There were no price swap agreements outstanding as of June 30, 2016.

~~The following table summarizes~~As of June 30, 2016, the Company’s financial assets and liabilities accounted for at fair value asconsisted of ~~September 30, 2015:~~

cash and cash equivalents of $67.4 million, a Level 1 measurement. As of ~~September~~June 30, ~~2015,~~2016, the ~~Company's~~Company’s other financial instruments, comprised solely of its fixed rate debt, had a carrying value of ~~$1.3~~$1.1 billion and a fair value of ~~$645.6~~$730.2 million. The fair market value of the ~~Company's~~Company’s fixed rate debt was based on quoted prices as of ~~September~~June 30, ~~2015,~~2016, a Level 2 measurement.

Basic earnings per share is determined without the effect of any outstanding potentially dilutive stock options or PSUs and diluted earnings per share is determined with the effect of outstanding stock options and PSUs that are potentially dilutive. Unvested share-based payment awards containing nonforfeitable rights to dividends are considered to be participatory securities and are 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~~Company’s common stock that may range from zero to up to ~~three~~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. The treasury stock method is used to measure the dilutive effect of PSUs. Basic and diluted ~~earnings~~income (loss) per share for the three months and ~~nine months~~six ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015 were determined as follows:

Three Months Ended September 30,

2015


2014

Loss


Shares


Per
Share


Loss

Shares


Per
Share

(In thousands, except per share amounts)

Net loss

$
(544,996
)





$
(1,903
)



Income allocable to unvested stock grants

—







(151
)



Basic net loss attributable to common stock

$
(544,996
)


46,150


$
(11.81
)

$
(2,054
)

46,651


$
(0.04
)
Effect of dilutive securities:









Stock options

—



—





—

—



Performance share units

—



—





—

—



Diluted net loss attributable to common stock

$
(544,996
)


46,150


$
(11.81
)

$
(2,054
)

46,651


$
(0.04
)

Nine Months Ended September 30,

2015


2014

Loss


Shares


Per
Share


Income
(Loss)

Shares


Per
Share

(In thousands, except per share amounts)

Net income (loss)

$
(758,566
)





$
1,160



Income allocable to unvested stock grants

—







(444
)



Basic net income (loss) attributable to common stock

$
(758,566
)


46,100


$
(16.45
)

$
716

46,628


$
0.02

Effect of dilutive securities:









Stock options

—



—





—

—



Performance share units

—



—





—

320



Diluted net income (loss) attributable to common stock

$
(758,566
)


46,100


$
(16.45
)

$
716

46,948


$
0.02

At ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014, 1,575,302~~2015, 354,974 and ~~1,207,527~~314,060 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~~Company’s stockholders. Weighted average shares of unvested restricted stock outstanding during the three months and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015 were as follows:

Options to purchase common stock and PSUs that were outstanding and that were excluded as anti-dilutive from the determination of diluted earnings per share are as follows:

For the ~~nine~~three and six months ended ~~September~~June 30, ~~2014,~~2016 and 2015, the excluded options that were anti-dilutive were at exercise prices in excess of the average stock price. ~~All stock options and~~Except for the three months ended June 30, 2016, all unvested PSUs were anti-dilutive to earnings and excluded from weighted average shares used in the computation of earnings per share in the ~~three months ended September 30, 2014 and the three months and nine months ended September 30, 2015~~periods presented due to the net loss in ~~the~~those periods.

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. ~~At September 30, 2015 and December 31, 2014, the Company's cash investments consisted of cash held in bank accounts.~~

The Company capitalizes interest on its unevaluated oil and gas property costs during periods when it is conducting exploration activity on this acreage. No interest was capitalized during the six months ended June 30, 2016. The Company capitalized interest of ~~$2.7~~$0.9 million for the ~~three~~six months ended ~~September~~June 30, ~~2014 and $0.9 million and $7.5 million for the nine months ended September 30,~~ 2015 ~~and 2014, respectively,~~ which reduced interest expense.

In May 2014, the Financial Accounting Standards Board ~~("FASB"~~(“FASB”) issued Accounting Standards Update ~~("ASU"~~(“ASU”) 2014-09,Revenue from Contracts with Customers (Topic 606)("“ASU ~~2014-09"~~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 evaluating the new guidance and has not determined the impact this standard may have on its financial statements or decided upon the method of adoption.

In August 2014, the FASB issued ASU No. 2014-15,Presentation of Financial Statements -— Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an ~~Entity's~~Entity’s Ability to Continue as a Going Concern("“ASU ~~2014-15"~~2014-15”). ASU 2014-15 provides guidance about ~~management's~~management’s responsibility to evaluate whether there is substantial doubt about an ~~entity's~~entity’s ability to continue as a going concern and sets rules for how this information should be disclosed in the financial statements. ASU 2014-15 is effective for annual periods ending after December 15, 2016 and interim periods thereafter. Early adoption is permitted. The Company has elected to not adopt ASU 2014-15 early and does not expect adoption of ASU 2014-15 to have any impact on its consolidated financial condition or results of operations.

In ~~April 2015,~~February 2016, the FASB issued ASU No. ~~2015-03,~~ ~~Interest-Imputation of Interest, Simplifying the Presentation of Debt Issuance Costs~~ 2016-02, Leases,("“ASU ~~2015-03"~~2016-02”). ASU ~~2015-03~~2016-02 requires ~~that debt issuance~~lessees to put most leases on their balance sheets, but recognize lease costs ~~related~~in their financial statements in a manner similar to ~~a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability.~~accounting for leases prior to ASC 2016-02. ASU ~~2015-03~~2016-02 is effective for annual periods ending after December 15, ~~2015~~2018 and interim periods thereafter. Early adoption is permitted. The Company is currently evaluating the new guidance and has ~~elected to~~ not ~~adopt ASU 2015-03 early and does not expect adoption of ASU 2015-03 to~~determined the impact this standard may have ~~a material impact~~ on its ~~consolidated~~ financial ~~condition~~statements or ~~results~~decided upon the method of ~~operations.~~adoption.

In March 2016, the FASB issued ASU No. 2016-09, Improvements to Employee Share-Based Payment Accounting,(“ASU 2016-09”). ASU 2016-09 will change how companies account for certain aspects of share-based payments, including recognizing the income tax effects of awards in the income statement when the awards vest or are settled. ASC 2016-09 revises guidance on employers’ accounting for employee’s use of shares to satisfy the employer’s statutory income tax withholding obligation and the treatment of forfeitures. ASU 2016-09 is effective for annual periods ending after December 15, 2016 and interim periods thereafter. Early adoption is permitted, but all guidance must be adopted in the same period. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements or decided upon the method of adoption.

On March 24, 2016, the Company received a notification from the New York Stock Exchange (the “NYSE”) notifying the Company that it was not in compliance with the NYSE’s continued listing standards. The Company ~~did not pay dividends~~is considered below criteria established by the NYSE as a result of the Company’s average stock price trading below $1.00 per share and its average market capitalization being less than $50.0 million, in each case over a consecutive 30 trading-day period. The Company has submitted and the NYSE has accepted a business plan to regain compliance with the NYSE’s continued listing standards. Comstock may regain compliance with the NYSE’s stock price standard at any time during a six-month cure period commencing on receipt of the ~~nine~~NYSE notification if its common stock has a closing stock price of at least $1.00 and an average closing stock price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month or the last trading day of the cure period. The Company must regain compliance with respect to its market capitalization within eighteen months ~~ended September 30, 2015, but paid dividends~~ of ~~$17.9 million during~~receipt of the ~~nine months ended September 30, 2014. In 2013,~~NYSE notification. Failure to regain compliance with the ~~Board~~NYSE’s continued listing

standards within the applicable time periods will result in the commencement of ~~Directors approved an open market share repurchase plan which permits the Company to repurchase up to $100.0 million~~suspension and delisting procedures. On July 29, 2016, Comstock completed a one-for-five (1:5) reverse split of its common stock onto address the ~~open market. The Company did not make any purchases under this plan during~~minimum stock price requirement.

At the ~~nine months ended September 30, 2015 or 2014, and future repurchases under this plan are limited under~~Company’s 2016 annual meeting of stockholders, the ~~terms~~stockholders approved an amendment to the Company’s restated articles of incorporation to increase the ~~Company's outstanding debt.~~

authorized shares of common stock to 50 million shares (such number adjusted for the one-for-five (1:5) reverse stock split).

In March 2015, Comstock issued $700.0 million of 10% senior secured notes (the ~~"Secured Notes"~~“Secured Notes”) which are due on March 15, 2020. Interest on the Secured Notes is payable semi-annually on each March 15 and September 15. Net proceeds from the issuance of the Secured Notes of ~~$684.0~~$683.8 million were used to retire the ~~Company's~~Company’s bank credit facility and for general corporate purposes. Comstock also has outstanding (i) ~~$387.5~~$288.5 million of 7¾7³⁄₄% senior notes (the ~~"2019 Notes"~~“2019 Notes”) which are due on April 1, 2019 and bear interest which is payable semi-annually on each April 1 and October 1 and (ii) ~~$211.6~~$174.6 million of 9½9¹⁄₂% senior notes (the ~~"2020 Notes"~~“2020 Notes”) which are due on June 15, 2020 and bear interest which is payable semi-annually on each June 15 and December 15. The Secured Notes are secured on a first-priority basis equally and ratably with the ~~Company's~~Company’s revolving credit facility described below, subject to payment priorities in favor of the revolving credit facility by the collateral securing the revolving credit facility, which consists of, among other things, at least 80% of the ~~Company's~~Company’s and its ~~subsidiaries'~~subsidiaries’ oil and gas properties. The Secured Notes, the 2019 Notes and the 2020 Notes are general obligations of Comstock and are guaranteed by all of ~~Comstock's~~Comstock’s subsidiaries. Such subsidiary guarantors are 100% owned and all of the guarantees are full and unconditional and joint and several obligations. There are no restrictions on the ability of Comstock to obtain funds from its subsidiaries through dividends or loans. As of ~~September~~June 30, ~~2015,~~2016, Comstock had no material assets or operations which are independent of its subsidiaries.

During the ~~nine~~six months ended ~~September~~June 30, ~~2015, the Company purchased $12.5~~2016, Comstock has retired $87.5 million in principal amount of the 2019 Notes and ~~$88.4~~$19.8 million ~~in principal amount~~ of the 2020 Notes in exchange in the aggregate for ~~$37.8 million. The~~the issuance of 2,748,403 shares of common stock and $3.5 million in cash. A gain of ~~$59.3~~$89.6 million was recognized on the ~~purchase~~exchanges and purchases of the 2019 Notes and the 2020 Notes during the six months ended June 30, 2016 for the difference between the market value of the stock on the closing date of the exchanges and sales and the ~~loss resulting from~~net carrying value of the ~~write-off of deferred loan costs associated with~~debt and the ~~Company's bank credit facility of $3.7 million are~~related net premium and net debt issuance costs. The gain is included in the net gain on extinguishment of debt, which is reported as a component of other income (loss).

~~In connection~~ During the six months ended June 30, 2015, the Company purchased $16.8 million in principal amount of the 2020 Notes for $7.8 million. The gain of $8.2 million recognized on the purchase of the 2020 Notes and the loss resulting from the write-off of deferred loan costs associated with the ~~issuance~~Company’s bank credit facility of $3.7 million are included in the ~~Secured Notes,~~ net gain on extinguishment of debt.

Comstock ~~entered into~~has a $50.0 million revolving credit facility with Bank of Montreal and Bank of America, N.A. The revolving credit facility is a four year credit commitment that matures on March 4, ~~2019~~.2019. Indebtedness under the revolving credit facility is guaranteed by all of the ~~Company's~~Company’s subsidiaries and is secured by substantially all of ~~Comstock's~~Comstock’s and its ~~subsidiaries'~~subsidiaries’ assets. Borrowings under the revolving credit facility bear interest, at ~~Comstock's~~Comstock’s option, at either (1) LIBOR plus 2.5% or (2) the base rate (which is the higher of the administrative ~~agent's~~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~~Company’s ability to make certain loans, investments and divestitures. The only financial covenants are the maintenance of a current ratio of at least 1.0 to 1.0 and the maintenance of an asset coverage ratio of proved developed reserves to total debt outstanding under the revolving credit facility of at least 2.5 to 1.0. The Company was in compliance with these covenants as of ~~September~~June 30, ~~2015.~~

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~~Company’s financial position or results of operations.

In connection with its exploration and development activities, the Company contracts for drilling rigs. As of September 30, 2015, the Company had commitments for contracted drilling services through November 2015 of $1.3 million.

The Company has entered into natural gas transportation and treating agreements through July 2019. Maximum commitments under these transportation agreements as of ~~September~~June 30, ~~2015~~2016 totaled ~~$7.1~~$5.3 million.

On ~~October~~August 1, ~~2015,~~2016 the Company ~~entered into~~filed with the Securities and Exchange Commission a ~~net operating loss carryforwards ("NOLs"~~registration statement on Form S-4 and commenced an exchange offer (the “Exchange Offer”) ~~rights plan (the "Rights Plan") with American Stock Transfer & Trust Company, LLC, as rights agent. In connection therewith, the board~~ of ~~directors~~new secured notes, and in certain instances warrants, in exchange for all of the Company’s Secured Notes, 2019 Notes and 2020 Notes. The Company ~~declared a dividend of one preferred share purchase right ("Right")~~is offering to exchange (i) new senior secured notes and warrants for ~~each outstanding share~~the $700.0 million principal amount of the ~~Company's~~of Secured Notes and (ii) second lien convertible notes for $463.1 million principal amount of the 2019 Notes and 2020 Notes. The new notes would contain the same interest rates and maturity dates as the existing notes but would in certain circumstances and terms allow the Company to pay the interest in-kind and with respect to the new second lien notes, subject to the Company obtaining stockholder approval, be convertible into shares of the Company’s common stock. The dividend was payable on October 16, 2015 to stockholders of record as of the close of business on October 12, 2015. In addition, one Right automatically attached to each share of common stock issued between the record date and the date when the Rights become exercisable.

The Rights Plan was adopted in an effort to prevent potential significant limitations under Section 382 of the Internal Revenue Code of 1986, as amended (the "Code"), on Comstock's ability to utilize its current NOLs to reduce its future tax liabilities. If Comstock experiences an "ownership change," as defined in Section 382 of the Code, the Company's ability to fully utilize its NOLs on an annual basis will be substantially limited, and the timing of the usage of the NOLs could be substantially delayed, which could accordingly significantly impair the value of those benefits. The Rights Plan works by imposing a significant penalty upon any person or group that acquires 4.9% or more of the Company's outstanding common stock without the approval of the board of directors (an "Acquiring Person"). The Rights Plan also gives discretion to the Board to determine that someone is an Acquiring Person even if they do not own 4.9% or more of the outstanding common stock but do own 4.9% or more in value of the Company's outstanding stock, as determined pursuant to Section 382 of the Code and the regulations promulgated thereunder. Stockholders who currently own 4.9% or more of the Company's common stock will not trigger the Rights unless they acquire additional shares, subject to certain exceptions set forth in the Rights Plan. In addition, the Board has established procedures to consider requests to exempt certain acquisitions of the Company's securities from the Rights Plan if the board of directors determines that doing so would not limit or impair the availability of the NOLs or is otherwise in the best interests of the Company.

ITEM 2: ~~MANAGEMENT'S~~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, ~~2014.~~2015 and as adjusted by our Current Report on Form 8-K dated August 1, 2016.

The prices for crude oil and natural gas have been highly volatile over the last twelve months, and we ~~are currently experiencing~~continue to experience a period of low prices primarily due to an oversupply of oil and natural gas. IfAs these prices remain low, we ~~will~~ continue to experience lower revenues and cash flows. We expect our oil production to continue to decline until we resume drilling on our properties. We anticipate that our natural gas production will increase through our ~~2015~~2016 drilling program focused on our Haynesville shale properties. We may also recognize further impairments of our producing oil and gas properties if oil and natural gas prices remain low and as a result the expected future cash flows from these properties becomes insufficient to recover their carrying value or ~~the Company does~~we do not have sufficient capital to develop ~~any~~ undeveloped reserves required to recover their carrying value. In addition, we may recognize additional impairments of our unevaluated oil and gas properties should we determine that we no longer intend to retain these properties for future ~~oil and natural gas~~ development.


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014		2016		2015		2016		2015
	(In thousands, except per unit amounts)								(In thousands, except per unit amounts)
Net Production Data:
Natural gas (Mmcf)										13,519		11,073		27,344		19,273
Oil (Mbbls)		635		1,125		2,595		3,172		355		924		772		1,960
Natural gas (Mmcf)		13,474		9,641		32,747		30,722
Natural gas equivalent (Mmcfe)		17,284		16,390		48,318		49,752		15,649		16,616		31,974		31,034
Revenues:
Natural gas sales									$	25,727	$	26,188	$	50,874	$	46,757
Oil sales	$	27,706	$	107,899	$	124,783	$	309,283		14,988		51,124		26,004		97,077
Natural gas sales		33,654		37,084		80,411		133,332

Total oil and gas sales	$	61,360	$	144,983	$	205,194	$	442,615	$	40,715	$	77,312	$	76,878	$	143,834

Expenses:
Production taxes	$	2,170	$	6,369	$	8,951	$	18,437	$	1,327	$	3,807	$	2,513	$	6,781
Gathering and transportation		3,729		3,125		9,842		10,039		4,025		3,260		8,390		6,113
Lease operating⁽¹⁾		16,687		15,858		49,650		44,899		12,988		17,827		25,948		32,963
Exploration expense		5,040		11,449		70,309		11,449		—		23,040		7,753		65,269
Depreciation, depletion and amortization		79,445		99,977		261,907		283,390		36,029		90,573		74,865		182,462
Average Sales Price:
Natural gas (per Mcf)	$	2.50	$	3.85	$	2.46	$	4.34	$	1.90	$	2.37	$	1.86	$	2.43
Oil (per Bbl)	$	43.63	$	95.92	$	48.08	$	97.51	$	42.21	$	55.34	$	33.69	$	49.53
Average equivalent (Mcfe)	$	3.55	$	8.85	$	4.25	$	8.90	$	2.60	$	4.65	$	2.40	$	4.63
Expenses ($ per Mcfe):
Production taxes	$	0.13	$	0.39	$	0.19	$	0.37	$	0.08	$	0.23	$	0.08	$	0.22
Gathering and transportation	$	0.22	$	0.19	$	0.20	$	0.20	$	0.26	$	0.20	$	0.26	$	0.20
Lease operating⁽¹⁾	$	0.96	$	0.97	$	1.03	$	0.90	$	0.83	$	1.07	$	0.81	$	1.06
Depreciation, depletion and amortization⁽²⁾	$	4.58	$	6.08	$	5.40	$	5.68	$	2.28	$	5.43	$	2.32	$	5.86

Our oil and natural gas sales decreased ~~$83.6~~$36.6 million ~~(58%~~(47%) in the ~~third~~second quarter of ~~2015~~2016 to ~~$61.4~~$40.7 million from ~~$145.0~~$77.3 million in the ~~third~~second quarter of ~~2014~~2015, primarily due to the substantial decline in oil and natural gas ~~prices. Gas~~prices and a decline in our oil production. Natural gas sales in the ~~third~~second quarter decreased 9%2% to ~~$33.7~~$25.7 million due to lower natural gas prices offset in part by higher ~~gas~~ production. Our natural gas production increased by ~~40%~~22% from the ~~third~~second quarter of ~~2014~~2015 while our realized natural gas price decreased by ~~35%~~20% during the same period. The increase in our natural gas production has been driven by our successful natural gas drilling program that we commenced in 2015. Oil sales in the ~~third~~second quarter of ~~2015~~2016 decreased by

~~74%~~ 71% to ~~$27.7~~$15.0 million from the ~~third~~second quarter of ~~2014~~2016 due to a ~~44%~~62% decrease in our oil production and a ~~55%~~24% decrease in our realized oil prices as compared with the ~~third~~second quarter of ~~2014.~~ 2015. The decline in oil production is attributable to the sale of our East Texas Eagle Ford shale properties in or near Burleson, Texas in 2015 and the lack of drilling activity in our South Texas Eagle Ford shale properties in South Texas.

In the first ~~nine~~six months of ~~2015,~~2016, our oil and natural gas sales decreased by ~~$237.4~~$66.9 million ~~(54%~~(47%) to ~~$205.2~~$76.9 million from ~~$442.6~~$143.8 million in the first ~~nine~~six months of ~~2014.~~2015. Natural gas ~~sales decreased by $52.9 million (40%) from 2014 and our oil~~ sales in the first ~~nine~~six months of 2016 increased by $4.1 million (9%) from 2015 while oil sales decreased by ~~$184.5~~$71.1 million ~~(60%~~(73%) from ~~2014. The decrease in~~2015. Our natural gas ~~sales is due to lower~~production increased by 42% from 2015 while our realized ~~gas prices of 43% offset in part by 7% higher~~ natural gas ~~production.~~price decreased by 23%. The decrease in oil sales is attributable to the ~~51%~~61% decline in our production and the 32% decrease in realized oil ~~prices and an 18% decrease in production as compared with the first nine months of 2014.~~ prices.

Production taxes decreased ~~$4.2~~$2.5 million to ~~$2.2~~$1.3 million for the ~~third~~second quarter of ~~2015~~2016 from ~~$6.4~~$3.8 million in the ~~third~~second quarter of ~~2014.~~2015. Production taxes of ~~$9.0~~$2.5 million for the first ~~nine~~six months of ~~2015~~2016 decreased ~~$9.4~~$4.3 million as compared with production taxes of ~~$18.4~~$6.8 million for the first ~~nine~~six months of ~~2014.~~2015. These decreases are mainly related to our lower oil and gas sales in ~~2015~~2016 as well as state exemptions on our Haynesville shale wells drilled in ~~2015.~~2015 and 2016.

Gathering and transportation costs for the ~~third~~second quarter of ~~2015~~2016 increased ~~$0.6~~$0.7 million to ~~$3.7~~$4.0 million as compared to ~~$3.1~~$3.3 million in the ~~third~~second quarter of ~~2014.~~2015. Gathering and transportation costs for the first ~~nine~~six months of ~~2015 decreased $0.2~~2016 increased $2.3 million to ~~$9.8~~$8.4 million as compared to ~~$10.0~~$6.1 million for the first ~~nine~~six months of ~~2014.~~2015. Our gathering and transportation costs have ~~been reduced with the benefit of~~increased due to the volume growth from our Haynesville shale drilling program.

Our lease operating expense of ~~$16.7~~$13.0 million for the ~~third~~second quarter of ~~2015 increased $0.8~~2016 decreased $4.8 million ~~(5%~~(27%) from operating expense of ~~$15.9~~$17.8 million for the ~~third~~second quarter of ~~2014.~~2015. Our lease operating expense for the first ~~nine~~six months of ~~2015~~2016 of ~~$49.7~~$25.9 million ~~increased $4.8~~decreased $7.1 million or ~~11%~~21% from our lease operating expense of ~~$44.9~~$33.0 million for the first ~~nine~~six months of ~~2014.~~2015. This ~~increase~~decrease primarily reflects ~~increased lifting~~lower costs associated with our declining oil ~~wells put onto production in 2014 as well as additional costs incurred related to the installation of artificial lift on many of our oil wells.~~production. Our lease operating expense of ~~$1.03~~$0.81 per Mcfe produced for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 was ~~$0.13~~$0.25 per Mcfe ~~higher~~lower than the lease operating expense of $1.06 per Mcfe for the same period in ~~2014.~~ 2015.

Exploration costs of ~~$5.0~~$7.8 million in the six months ended June 30, 2016 primarily related to impairments of unevaluated leases recognized in the first quarter of 2016. Exploration costs of $23.0 million and ~~$70.3~~$65.3 million in the three ~~months~~ and ~~nine~~six months ended ~~September~~June 30, 2015, respectively, primarily include impairments of unevaluated leases and rig termination fees. Exploration costs of $11.4 million in the three months and nine months ended September 30, 2014 relate to exploratory well costs that were expensed as a result of mechanical problems encountered during completion which caused us to abandon the well.

Depreciation, depletion and amortization ("(“DD~~&A"~~&A”) decreased ~~$20.6~~$54.6 million ~~(21%~~(60%) to ~~$79.4~~$36.0 million in the ~~third~~second quarter of ~~2015~~2016 from ~~$100.0~~$90.6 million in the ~~third~~second quarter of ~~2014.~~2015. Our DD&A per equivalent Mcf produced decreased ~~$1.50 (25%~~$3.15 (58%) to ~~$4.58~~$2.28 for the three months ended ~~September~~June 30, ~~2015~~2016 from ~~$6.08~~$5.43 for the three months ended ~~September~~June 30, ~~2014. The lower rate in the third quarter of 2015 reflects the lower finding costs of natural gas wells drilled in~~ 2015. DD&A for the first ~~nine~~six months of ~~2015~~2016 of ~~$261.9~~$74.9 million decreased ~~$21.5~~$107.6 million ~~(8%~~

(59%) from DD&A expense of ~~$283.4~~$182.5 million for the ~~nine~~six months ended ~~September~~June 30, ~~2014.~~2015. For the first ~~nine~~six months of ~~2015,~~2016, our per unit DD&A rate of ~~$5.40~~$2.32 decreased ~~$0.28 (5%~~$3.54 (60%) from our DD&A rate of ~~$5.68~~$5.86 for the first ~~nine~~six months of ~~2014.~~2015. The lower ~~DD&A rate per Mcfe primarily reflects~~rates in 2016 reflect the impairments we recognized in 2015 as well as the increase in production from the lower ~~finding~~cost Haynesville shale properties.

General and administrative expenses, which are reported net of overhead reimbursements, decreased to $5.7 million for the second quarter of 2016 from $7.2 million in the second quarter of 2015. Included in general and administrative expenses are stock-based compensation of $1.2 million and $2.1 million for the three months ended June 30, 2016 and 2015, respectively. For the first six months of 2016, general and administrative expenses of $11.2 million decreased $3.9 million (26%) from general and administrative expenses for the six months ended June 30, 2015 of $15.1 million. Included in general and administrative expense is stock-based compensation of $2.5 million and $4.0 million for the six months ended June 30, 2016 and 2015, respectively. The lower general and administrative costs are attributable to a reduction in personnel and related ~~to our natural gas production.~~compensation costs in 2016.

We assess the need for impairment of the capitalized costs for our oil and gas properties on a property basis. ~~During the three months ended September 30, 2015, we~~We recognized an impairment ~~charge~~charges of ~~$544.7~~$3.7 million and $2.4 million on our oil and gas properties during the six months ended June 30, 2016 and June 30, 2015, respectively, primarily due to the decline in ~~management's~~management’s oil and natural gas price outlook.

~~General~~Also included in impairments for the six months ended June 30, 2016 is an impairment of $20.8 million to reduce the carrying value of our South Texas natural gas properties classified as assets held for sale to their net realizable value less costs to sell. The net loss on sales and ~~administrative expenses, which are reported net~~exchange of ~~overhead reimbursements, decreased to $5.7~~oil and gas properties of $0.9 million for the ~~third~~first six months of 2016 reflects the non-monetary exchange we completed in January, 2016 and the sale of certain other oil and gas properties. The loss on sale of oil and gas properties of $111.8 million for the six months ended June 30, 2015 relates to our sale of our Burleson County, Texas oil properties.

Interest expense decreased $4.9 million to $28.9 million for the second quarter of ~~2015~~2016 from ~~$7.9~~interest expense of $33.8 million in the ~~third~~second quarter of ~~2014. Included~~2015. We did not capitalize interest during the three months ended June 30, 2016 and 2015. The decrease in ~~general and administrative expenses are stock-based compensation of $2.1 million and $2.8 million~~interest expense for the three months ended ~~September~~June 30, ~~2015 and 2014, respectively. For~~2016 mainly reflects the ~~first nine months~~interest savings from our repurchases of ~~2015, general and administrative expenses of $20.8~~our senior notes. Interest expense increased $4.2 million decreased $5.1 million (20%) from general and administrative expenses for the nine months ended September 30, 2014 of $25.9 million. Included in general and administrative expense is stock-based compensation of $6.1 million and $7.8to $58.8 million for the ~~nine~~first six months ~~ended September 30, 2015 and 2014, respectively. The lower general and administrative costs are attributable to a reduction in personnel and related compensation costs in 2015.~~

~~Interest expense increased $17.3 million to $32.2 million for the third quarter~~ of ~~2015~~2016 from interest expense of ~~$14.9~~$54.6 million in the ~~third quarter~~first six months of ~~2014.~~2015. We did not capitalize any interest during the ~~three~~six months ended ~~September~~June 30, ~~2015~~2016 and we capitalized interest of $2.7 million during the three months ended September 30, 2014. Interest expense increased $43.3 million to $86.7 million for the first nine months of 2015 from interest expense of $43.4 million in the first nine months of 2014. We capitalized interest of $0.9 ~~million and $7.5~~ million on our unevaluated properties during the ~~nine~~six months ended ~~September~~June 30, ~~2015 and 2014, respectively. In addition to the lower capitalized interest, these increases are primarily related to the~~2015. The increase in ~~debt outstanding during 2015, including~~interest expense for the six months ended June 30, 2016 primarily relates to the issuance of $700.0 million of senior secured notes in March ~~2015.~~2015, which was partially offset by the lower interest from our debt reduction program.

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 that covered a portion of our production were ~~$1.1 million~~$18,000 and ~~$1.7~~$0.7 million for the three months and ~~nine~~six months ended ~~September~~June 30, ~~2015. In 2014, we~~2016, respectively. We had no cash settlements for crude oil ~~price~~or natural gas swaps ~~that covered a portion of our production. Gains related to our oil derivative financial instruments were $12.0 million in~~during the three months ~~ended September 30, 2014~~ and ~~losses related to our derivative financial statements were $2.8 million in the nine~~six months ended ~~September~~June 30, ~~2014. The following table presents our crude oil equivalent prices before and after the effect of cash settlements of our derivative financial instruments:~~

2015. The following table presents our natural gas ~~equivalent~~ prices before and after the effect of cash settlements of our derivative financial instruments:

During the six months ended June 30, 2016 and 2015, we recognized ~~a loss of $111.8 million related to the sale of certain oil and gas properties and~~ a net gain on extinguishment of debt of ~~$55.6~~$89.6 million ~~during~~and $4.5 million, respectively. We retired $87.5 million and $19.8 million of principal of the ~~nine~~2019 Notes and the 2020 Notes in the six months ended ~~September~~June 30, ~~2015.~~ 2016 and 2015, respectively, as part of our debt reduction program.

Income taxes for the ~~third quarter of 2015~~three months ended June 30, 2016 were a ~~benefit~~provision of ~~$30.6 million~~$88,000 as compared to a benefit of ~~$0.5~~$72.7 million for the three months ended ~~September~~June 30, ~~2014.~~2015. Our effective tax rate for the three months ended ~~September~~June 30, ~~2015~~2016 was a ~~benefit~~provision of ~~5.3%~~1.8% as compared to a benefit of ~~20.5%~~35.0% for the three months ended ~~September~~June 30, ~~2014.~~2015. Income taxes for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 were a ~~benefit~~provision of ~~$144.9~~$4.5 million as compared to a ~~provision~~benefit of ~~$1.5~~$114.3 million for the ~~nine~~six months ended ~~September~~June 30, ~~2014.~~2015. Our effective tax rate was ~~16.0%~~a provision of 9.6% for the first ~~nine~~six months of 2016 as compared to a benefit of 34.9% for the first six months of 2015. 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. No benefit for income taxes was reflected on the loss in the first six months of 2016 due to the increase to our valuation allowances related to federal and certain state net operating losses. The effective tax rate for the first six months of 2015 differed slightly from the expected rate of 35% primarily because of state taxes.

We reported net income of $4.9 million, or $0.41 per diluted share, for the three months ended June 30, 2016 as compared to 55.6% for the first nine months of 2014. The effective tax rates for 2015 and 2014 primarily reflect the effect of certain non-deductible expenses and a valuation allowance recognized on deferred tax assets in 2015 of $189.4 million.

~~We reported~~ a net loss of ~~$545.0~~$135.1 million, or ~~$11.81~~$14.64 per share, for the three months ended ~~September~~June 30, ~~2015~~2015. We reported a net loss of $51.7 million, or $4.82 per share, for the six months ended June 30, 2016, as compared to a net loss of ~~$1.9~~$213.6 million, or 4¢$23.18 per share, for the ~~three~~six months ended ~~September~~June 30, 2014. We reported a net loss of $758.6 million, or $16.45 per share, for the nine months ended September 30, 2015, as compared to net income of $1.2 million, or 2¢ per diluted share, for the nine months ended September 30, 2014.2015. The net loss in the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 was primarily due to the ~~substantial~~ oil and gas property impairment charges recognized, ~~the loss on sale of oil and gas properties,~~ lower oil and natural gas prices ~~higher exploration costs~~ and higher interest expense.

Funding for our activities has historically been provided by our operating cash flow, debt or equity financings or proceeds from asset sales. For the ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, our primary source of funds ~~were~~was cash on hand. Cash used for operating activities for the six months ended June 30, 2016 was $31.2 million as compared to cash provided by operating activities of $23.5 million, net borrowings of $40.0 million under our bank credit facility and net proceeds from our senior secured notes offering of $684.0 million. Our net cash flow from operating activities (excluding working capital changes) decreased $266.3 million (87%) in the first nine months of 2015 to $39.5 million from $305.8$24.2 million for the first ~~nine~~six months of ~~2014.~~2015. This decrease primarily reflects our lower revenues from oil and gas ~~sales.~~sales and working capital changes.

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 ~~nine~~six months of ~~2015,~~2016, we incurred capital expenditures ~~on an accrual basis,~~ of ~~$209.2~~$30.3 million primarily for our development and exploration activities.

The following table summarizes our capital expenditure activity, on an accrual basis, for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

~~We expect to spend approximately $28 million for developmental and exploratory drilling and for acquisition of leases during the fourth quarter of 2015.~~ We expect to fund our development and exploration activities with future operating cash flow, proceeds from anticipated asset sales and from cash on hand.

Our cash flows for the first six months of 2016 were significantly impacted by the low oil and natural gas prices and a reduction in accounts payable due to our lower drilling activity. The timing of most of our capital expenditures is discretionary because we have no material long-term capital expenditure ~~commitments except for commitments for contract drilling services.~~commitments. Consequently, we have a significant degree of flexibility to adjust the level of our capital expenditures as circumstances warrant. ~~In March 2015, we released one of the contracted~~We presently have no contracts for future drilling ~~rigs for the payment of a $1.7 million early termination fee. As of September 30, 2015, we have one drilling rig under contract through November 2015 at a cost of $1.3 million. In addition, we~~services. We have maximum commitments of ~~$7.1~~$5.3 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. These payments~~properties which are currently estimated to be incurred primarily after ~~2019.~~ 2020.

With the substantial decline in oil and natural gas prices in 2015, which have continued into 2016, we continue to experience declining cash flows and reductions in our overall liquidity. At current oil and natural gas prices, operating cash flow was not sufficient to cover our fixed debt service costs. Our capital expenditures have been funded with asset sale proceeds or from cash on hand. Beginning in 2015, we redirected our drilling program to natural gas and drilled ten successful horizontal wells on Haynesville and Bossier shale properties in North Louisiana employing an enhanced completion design using longer laterals and larger well stimulations. The well results were successful but natural gas prices substantially declined in response to a very warm winter. In order to preserve liquidity, we recently released our last operated rig after drilling and completing three additional successful Haynesville shale wells in 2016. While the reduction in drilling activity will allow us to preserve more of the cash on our balance sheet, it will result in future reductions to our natural gas production and proved oil and natural gas reserves.

We ~~record~~are planning to resume our drilling program later this year. We are planning to drill five (4.5 net) additional wells in 2016 and 19 (15.7 net) wells in 2017. Capital expenditures for this program would approximate $46.0 million in the second half of 2016 and $147.0 million in 2017. Restarting the drilling program is dependent on successful completion of the Exchange Offer. The Exchange Offer, if successful, would free up cash flow from operations to fund our capital expenditures. To the extent that the Exchange Offer is not completed, we will pursue other initiatives to enhance liquidity, which may not be sufficient to fund this drilling program. Such initiatives could include additional asset divestitures or entering into a ~~separate liability for these asset retirement obligations which totaled $15.1 million as of September 30, 2015.~~drilling joint venture on our Haynesville shale properties.

In March 2015, we issued $700.0 million of 10% senior secured notes (the ~~"Secured Notes"~~“Secured Notes”) which are due on March 15, 2020. Interest on the Secured Notes is payable semi-annually on each March 15 and September 15. Net proceeds from the issuance of the Secured Notes of ~~$684.0~~$683.8 million were used to retire our bank credit facility and for general corporate purposes. We also have outstanding (i) ~~$387.5~~$288.5 million of 7¾7³⁄₄% senior notes (the ~~"2019 Notes"~~“2019 Notes”) which are due on April 1, 2019 and bear interest which is payable semi-annually on each April 1 and October 1 and (ii) ~~$211.6~~$174.6 million of 9½9¹⁄₂% senior notes (the ~~"2020 Notes"~~“2020 Notes”) which are due on June 15, 2020 and bear interest which is payable semi-annually on each June 15 and December 15. The Secured Notes are secured on a first priority basis equally and ratably with our revolving credit facility described below, subject to payment priorities in favor of the revolving credit facility by the collateral securing the revolving credit facility, which consists of, among other things, at least 80% of our and its ~~subsidiaries'~~subsidiaries’ oil and gas properties. The Secured Notes, the 2019 Notes and 2020 Notes are our general obligations and are guaranteed by all of our subsidiaries. Such subsidiary guarantors are 100% owned and all of the guarantees are full and unconditional and joint and several obligations. There are no restrictions on our ability to obtain funds from our subsidiaries through dividends or loans. As of ~~September~~June 30, ~~2015,~~2016, we had no material assets or operations which are independent of our subsidiaries.

During the ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, we ~~purchased $12.5~~retired $87.5 million in principal amount of the 2019 Notes and ~~$88.4~~$19.8 million ~~in principal amount~~ of the 2020 Notes in exchange in the aggregate for ~~$37.8 million. The~~the issuance of 2,748,403 shares of common stock and $3.5 million in cash. A gain of ~~$59.3~~$89.6 million was recognized on the ~~purchase~~exchanges and purchases of the 2019 Notes and the 2020 Notes during the six months ended June 30, 2016 for the difference between the market value of the stock on the closing date of the exchanges and sales and the ~~loss resulting from~~net carrying value of the ~~write-off of deferred loan costs associated with our prior bank credit facility of $3.7 million are~~debt

and the related net premium and net debt issuance costs. The gain is included in the net gain on extinguishment of debt, which is reported as a component of other income (loss).

~~In connection with~~During the ~~issuance~~six months ended June 30, 2015, we purchased $16.8 million in principal amount of the ~~Secured~~2020 Notes ~~we entered into~~for $7.8 million. The gain of $8.2 million recognized on the purchase of the 2020 Notes and the loss resulting from the write-off of deferred loan costs associated with our bank credit facility of $3.7 million are included in the net gain on extinguishment of debt.

We have a $50.0 million revolving credit facility with Bank of Montreal and Bank of America, N.A. The revolving credit facility is a four year credit commitment that matures on March 4, 2019. Indebtedness under the revolving credit facility is secured by substantially all of our and our ~~subsidiaries'~~subsidiaries’ assets and is guaranteed by all of our subsidiaries. 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~~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 consolidated 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 of at least 1.0 to 1.0 and the maintenance of an asset coverage ratio of proved developed reserves to total debt outstanding under the revolving credit facility of at least 2.5 to 1.0. We were in compliance with these covenants as of ~~September~~June 30, ~~2015.~~2016.

On August 1, 2016 we filed with the Securities and Exchange Commission a registration statement on Form S-4 and commenced an exchange offer (the “Exchange Offer”) of new secured notes, and in certain instances warrants, in exchange for all of our Secured Notes, 2019 Notes and 2020 Notes. We are offering to exchange (i) new senior secured notes and warrants for the $700.0 million principal amount of the Secured Notes and (ii) second lien convertible notes for $463.1 million principal amount of the 2019 Notes and 2020 Notes. The new notes would contain the same interest rates and maturity dates as the existing notes but would in certain circumstances and terms allow us to pay the interest in-kind and with respect to the new second lien notes, subject to our obtaining stockholder approval, be convertible into shares of the Company’s common stock.

Upon successful completion of the Exchange Offer, we believe that our future cash flow from operations, proceeds from asset sales, cash on hand and available borrowings under our revolving credit facility will be sufficient to fund our operations and future growth as contemplated under our current business plan. However, if our plans or assumptions change or if our assumptions prove to be inaccurate, we may be required to seek additional capital. We cannot provide any assurance that we will be able to obtain such capital, or if such capital is available, that we will be able to obtain it on acceptable terms.

Future use of our federal 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 would result in a substantial portion of our net operating loss carryforwards being eliminated or becoming restricted, and we would need to recognize a valuation allowance reflecting the restricted use of these net operating loss carryforwards in the period when such an ownership change occurred. We may also need to recognize additional valuation allowances on our net operating loss carryforwards in future periods if we incur significant losses and accordingly a tax benefit may not be recognized on such losses. ~~On October 1,~~In 2015, we adopted a Rights Plan intended to prevent these potential limitations on our ability to utilize our net operating loss carryforwards. We expect an ownership change to occur if we are able to complete the Exchange Offer that we initiated on August 1, 2016.

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. Based on our oil and natural gas production for the ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016 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 ~~from continuing operations~~ by approximately ~~$3.1~~$2.5 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 ~~$2.5~~$0.7 million.

We have hedged a portion of our price risks associated with our gas sales. As of September 30, 2015, our outstanding gas price swap agreements had a fair asset value of $1.3 million. A change in the fair value of our gas swaps that would result from a 10% change in commodities prices at September 30, 2015 would be $0.4 million. Such a change in fair value could be a gain or a loss depending on whether prices increase or decrease.

Gains and losses on settlements and changes in the fair value of our swap agreements are reported as a separate component of other income (expenses) in the consolidated statement of operations. None of our derivatives contracts have margin requirements or collateral provisions that could require funding prior to the scheduled cash settlement date.

At ~~September~~June 30, ~~2015,~~2016, we had approximately ~~$1.3~~$1.2 billion principle amount of long-term debt outstanding. Of this amount, $700.0 million bears interest at a fixed rate of 10%, ~~$387.5~~$288.5 million bears interest at a fixed rate of 7¾7³⁄₄% and ~~$211.6~~$174.6 million bears interest at a fixed rate of 9½9¹⁄₂%. The fair market value of our fixed rate debt as of ~~September~~June 30, ~~2015~~2016 was ~~$645.6~~$730.2 million based on the market price of approximately ~~50%~~64% of the face amount. At ~~September~~June 30, ~~2015,~~2016, we had no 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.

As of ~~September~~June 30, ~~2015,~~2016, 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 ~~September~~June 30, ~~2015~~2016 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 ~~September~~June 30, ~~2015,~~2016, that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

The following risk factor updates the Risk Factors included in our Annual Report on Form 10-K for the year ended December 31, 2015 (the “Annual Report”). Except as set forth below, there have been no material changes to the risks described in the Annual Report.

We have received a notice of non-compliance with continued listing standards from the New York Stock Exchange (the “NYSE”) for our common stock. If we are unable to avoid the delisting of our common stock from the NYSE, it could have a substantial effect on our liquidity and results of operations.

On March 24, 2016, we received a notification from the NYSE informing us that we were no longer in compliance with the NYSE’s continued listing standards for our common stock because the average closing price of our common stock and our average market capitalization have fallen below the NYSE’s requirements. The NYSE’s continued listing standards require that (i) the average closing price of a listed company’s common stock be at least $1.00 per share and (ii) a listed company’s equity market capitalization be at least $50.0 million, in each case over a consecutive 30 trading-day period. As of July 29, 2016, the average closing price of our common stock over the preceding 30 trading-day period was $0.84 per share and our average equity market capitalization over the same period was $52.5 million.

We have submitted and the NYSE has accepted a business plan to regain compliance with the NYSE’s continued listing standards. We may regain compliance with the NYSE’s stock price standard at any time during a six-month cure period commencing on receipt of the NYSE notification if our common stock has a closing stock price of at least $1.00 and an average closing stock price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month or the last trading day of the cure period. We must regain compliance with respect to our market capitalization within eighteen months of receipt of the NYSE notification. Failure to regain compliance with the NYSE’s continued listing standards within the applicable time periods will result in the commencement of suspension and delisting procedures. On July 29, 2016, we completed a one-for-five (1:5) reverse split of our common stock to address the minimum stock price requirement.

The NYSE notification did not affect our business operations or our SEC reporting requirements and did not conflict with or cause an event of default under any of our material debt or other agreements. However, if our common stock ultimately were to be delisted for any reason, it could negatively impact us by (i) reducing the liquidity and market price of our common stock; (ii) reducing the number of investors willing to hold or acquire our common stock, which could negatively impact our ability to raise equity financing; (iii) limiting our ability to use a registration statement to offer and sell freely tradable securities, thereby preventing us from accessing the public capital markets; and (iv) impairing our ability to provide equity incentives to our employees.

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.


Large accelerated filer x¨	Accelerated filer ¨x	Non-accelerated filer ¨	Smaller reporting company ¨
	(Do not check if a smaller reporting company)


		Page
PART I. Financial Information

Item 1. Financial Statements (Unaudited):

Consolidated Balance Sheets - ~~September~~ June 30, ~~2015~~2016 and December 31, ~~2014~~2015			4
Consolidated Statements of Operations - Three Months and ~~Nine~~Six Months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015			5
Consolidated Statement of Stockholders’ ~~Equity~~ ~~Nine~~Deficit - Six Months ended ~~September~~June 30, ~~2015~~2016			6
Consolidated Statements of Cash Flows - ~~Nine~~ Six Months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015			7
Notes to Consolidated Financial Statements			8

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	17		18

Item 3. Quantitative and Qualitative Disclosure About Market Risk	21		23

Item 4. Controls and Procedures	22		24

PART II. Other Information

Item 1A. Risk Factors			25

Item 6. Exhibits	23		25
EX-31.1
EX-31.2
EX-32.1
EX-32.2
EX-101 INSTANCE DOCUMENT
EX-101 SCHEMA DOCUMENT
EX-101 CALCULATION LINKBASE DOCUMENT
EX-101 LABELS LINKBASE DOCUMENT
EX-101 PRESENTATION LINKBASE DOCUMENT
EX-101 DEFINITION LINKBASE DOCUMENT


	June 30, 2016			December 31, 2015
	(In thousands)
ASSETS

Cash and Cash Equivalents	$	67,412		$	134,006
Accounts Receivable:
Oil and gas sales		16,075			15,241
Joint interest operations		2,387			3,552
Derivative Financial Instruments		—			1,446
Assets Held for Sale		42,542			—
Other Current Assets		2,339			1,993

Total current assets		130,755			156,238
Property and Equipment:
Unproved oil and gas properties		76,391			84,144
Oil and gas properties, successful efforts method		3,768,602			4,332,222
Other		19,532			19,521
Accumulated depreciation, depletion and amortization		(2,949,175	)		(3,397,467	)

Net property and equipment		915,350			1,038,420
Other Assets		1,121			1,192

	$	1,047,226		$	1,195,850

LIABILITIES AND STOCKHOLDERS’ DEFICIT

Accounts Payable	$	46,601		$	57,276
Accrued Liabilities		40,220			38,444

Total current liabilities		86,821			95,720
Long-term Debt		1,145,190			1,249,330
Deferred Income Taxes		6,510			1,965
Reserve for Future Abandonment Costs		15,972			20,093

Total liabilities		1,254,493			1,367,108
Commitments and Contingencies
Stockholders’ Deficit:
Common stock — $0.50 par, 50,000,000 shares authorized, 12,504,562 and 9,544,035 shares outstanding at June 30, 2016 and December 31, 2015, respectively		6,253			4,772
Additional paid-in capital		518,905			504,670
Accumulated deficit		(732,425	)		(680,700	)

Total stockholders’ deficit		(207,267	)		(171,258	)

	$	1,047,226		$	1,195,850


	Common Stock (Shares)			Common Stock – Par Value			Additional Paid-in Capital			Accumulated Deficit			Total
	(In thousands)

Balance at January 1, 2016		9,544		$	4,772		$	504,670		$	(680,700	)	$	(171,258	)
Stock-based compensation		232			116			2,377			—			2,493
Restricted stock used for tax withholdings		(42	)		(21	)		(292	)		—			(313	)
Stock issued in exchange for debt		2,771			1,386			12,150			—			13,536
Net loss		—			—			—			(51,725	)		(51,725	)

Balance at June 30, 2016		12,505		$	6,253		$	518,905		$	(732,425	)	$	(207,267	)


	Six Months Ended June 30,
	2016			2015
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(51,725	)	$	(213,570	)
Adjustments to reconcile net loss to net cash provided by (used for) operating activities:
Net loss on sales and exchange of oil and gas properties		907			111,830
Deferred income taxes		4,519			(114,785	)
Leasehold impairments and other exploration costs		7,753			65,269
Impairment of oil and gas properties		24,460			2,387
Depreciation, depletion and amortization		74,865			182,462
Gain on derivative financial instruments		(674	)		(627	)
Settlements of derivative financial instruments		2,120			—
Net gain on extinguishment of debt		(89,576	)		(4,532	)
Amortization of debt discount, premium and issuance costs		2,533			2,564
Stock-based compensation		2,493			3,982
Excess income taxes from stock-based compensation		—			1,903
Decrease in accounts receivable		331			17,125
Decrease (increase) in other current assets		(346	)		7,600
Decrease in accounts payable and accrued liabilities		(8,864	)		(37,370	)

Net cash provided by (used for) operating activities		(31,204	)		24,238

CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures		(33,654	)		(197,263	)
Proceeds from asset sales		2,067			—

Net cash used for investing activities		(31,587	)		(197,263	)

CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings		—			740,000
Payments to retire debt		(3,397	)		(420,288	)
Debt and equity issuance costs		(93	)		(16,115	)
Tax withholdings related to restricted stock		(313	)		(526	)
Excess income taxes from stock-based compensation		—			(1,903	)

Net cash provided by (used for) financing activities		(3,803	)		301,168

Net increase (decrease) in cash and cash equivalents		(66,594	)		128,143
Cash and cash equivalents, beginning of period		134,006			2,071

Cash and cash equivalents, end of period	$	67,412		$	130,214

	September 30, 2015			December 31, 2014
	(In thousands)
ASSETS

Cash and Cash Equivalents	$	163,840		$	2,071
Accounts Receivable:
Oil and gas sales		19,680			32,849
Joint interest operations		4,084			16,192
Derivative Financial Instruments		1,314			—
Other Current Assets		2,933			10,105
Total current assets		191,851			61,217
Property and Equipment:
Unevaluated oil and gas properties		80,449			201,459
Oil and gas properties, successful efforts method		4,299,265			4,282,088
Other		19,515			19,630
Accumulated depreciation, depletion and amortization		(3,083,879	)		(2,305,008	)
Net property and equipment		1,315,350			2,198,169
Other Assets		22,473			14,951
	$	1,529,674		$	2,274,337

LIABILITIES AND STOCKHOLDERS’ EQUITY

Accounts Payable	$	51,213		$	117,329
Accrued Liabilities		39,764			44,842
Total current liabilities		90,977			162,171
Long-term Debt		1,297,312			1,070,445
Deferred Income Taxes		10,981			154,547
Reserve for Future Abandonment Costs		15,106			14,900
Other Non-Current Liabilities		—			2,002
Total liabilities		1,414,376			1,404,065
Commitments and Contingencies
Stockholders’ Equity:
Common stock – $0.50 par, 75,000,000 shares authorized, 47,725,176 and 46,858,415 shares outstanding at September 30, 2015 and December 31, 2014, respectively		23,863			23,429
Additional paid-in capital		483,592			480,434
Accumulated earnings (deficit)		(392,157	)		366,409
Total stockholders’ equity		115,298			870,272
	$	1,529,674		$	2,274,337

	Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
Revenues:	(In thousands, except per share amounts)
Oil sales	$	27,706		$	107,899		$	124,783		$	309,283
Natural gas sales		33,654			37,084			80,411			133,332
Total revenues		61,360			144,983			205,194			442,615

Operating expenses:
Production taxes		2,170			6,369			8,951			18,437
Gathering and transportation		3,729			3,125			9,842			10,039
Lease operating		16,687			15,858			49,650			44,899
Exploration		5,040			11,449			70,309			11,449
Depreciation, depletion and amortization		79,445			99,977			261,907			283,390
General and administrative		5,653			7,927			20,795			25,910
Impairment of oil and gas properties		544,714			15			547,101			271
(Gain) loss on sale of oil and gas properties		(52	)		—			111,778			—
Total operating expenses		657,386			144,720			1,080,333			394,395

Operating income (loss)		(596,026	)		263			(875,139	)		48,220

Other income (expenses):
Interest income		138			—			308			—
Net gain on extinguishment of debt		51,054			—			55,586			—
Gain (loss) on derivative financial instruments		1,078			12,033			1,705			(2,763	)
Other income		273			223			746			513
Interest expense		(32,159	)		(14,912	)		(86,720	)		(43,359	)

Total other income (expenses)		20,384			(2,656	)		(28,375	)		(45,609	)

Income (loss) before income taxes		(575,642	)		(2,393	)		(903,514	)		2,611
Benefit from (provision for) income taxes		30,646			490			144,948			(1,451	)
Net income (loss)	$	(544,996	)	$	(1,903	)	$	(758,566	)	$	1,160

Net income (loss) per share:
Basic	$	(11.81	)	$	(0.04	)	$	(16.45	)	$	0.02
Diluted	$	(11.81	)	$	(0.04	)	$	(16.45	)	$	0.02

Dividends per common share	$	—		$	0.125		$	—		$	0.375

Weighted average shares outstanding:
Basic		46,150			46,651			46,100			46,628
Diluted		46,150			46,651			46,100			46,948


	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In thousands)
Total oil and gas sales	$	1,728		$	14,208		$	3,528		$	22,755
Total operating expenses⁽¹⁾		(1,712	)		(18,616	)		(3,399	)		(72,977	)

Operating income (loss)	$	16		$	(4,408	)	$	129		$	(50,222	)

	Fair Value		Impairment		Management's Price Outlook		Annual Discount Rate
	Fair Value		Impairment		Oil	Gas	Annual Discount Rate
	(In thousands)				(Per barrel)	(Per Mcf)
Oil properties	$	330,257	$	405,308	$73.70	$4.04	10%
Natural gas properties	$	61,625	$	139,406	$75.91	$3.91	10%

	As of September 30, 2015		As of December 31, 2014
	(In thousands)				As of June 30, 2016		As of December 31, 2015
					(In thousands)
Accrued interest					$	26,892	$	29,075
Accrued drilling costs	$	4,492	$	26,269		2,005		5,306
Accrued interest		23,796		9,011
Accrued ad valorem taxes		4,500		—		2,400		—
Current deferred income taxes payable		460		—
Accrued rig termination fees		—		2,600
Asset retirement obligation of assets held for sale						3,442		—
Other accrued liabilities		6,516		6,962		5,481		4,063
	$	39,764	$	44,842
					$	40,220	$	38,444

	Carrying Value Measured at Fair Value at September 30, 2015		Level 1		Level 2
	(In thousands)
Assets measured at fair value on a recurring basis:
Cash and cash equivalents held in bank accounts	$	163,840	$	163,840	$	—
Derivative financial instruments		1,314		—		1,314
Total assets	$	165,154	$	163,840	$	1,314

	(In thousands)
7³⁄₄% Senior Notes due 2019	$	391,496
10% Senior Secured Notes due 2020		700,000
9¹⁄₂% Senior Notes due 2020		205,816
	$	1,297,312


	(In thousands)
7³⁄₄ % Senior Notes due 2019:
Principal	$	288,516
Premium, net of amortization		2,325
Debt issue costs, net of amortization		(2,464	)
9¹⁄₂ % Senior Notes due 2020:
Principal		174,607
Discount, net of amortization		(4,008	)
Debt issue costs, net of amortization		(1,913	)
10% Senior Secured Notes due 2020:
Principal		700,000
Debt issue costs, net of amortization		(11,873	)

	$	1,145,190


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014		2016		2015		2016		2015
Average Realized Oil Price:
Natural gas, per Mcf	$	2.50	$	3.85	$	2.46	$	4.34	$	1.90	$	2.37	$	1.86	$	2.43
Cash settlements of derivative financial instruments, per Mcf		0.03		—		0.01		—		0.09		—		0.08		—

Price per Mcf, including cash settlements of derivative financial instruments	$	2.53	$	3.85	$	2.47	$	4.34	$	1.99	$	2.37	$	1.94	$	2.43


Exhibit No.		Description
31.1*
31.1*		Section 302 Certification of the Chief Executive Officer.
31.2*
31.2*		Section 302 Certification of the Chief Financial Officer.
~~32.1†~~
32.1†		Certification for the Chief Executive Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002.
~~32.2†~~
32.2†		Certification for the Chief Financial Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002.


Exhibit No.		Description
101.INS*
101.INS*		XBRL Instance Document
101.SCH*
101.SCH*		XBRL Schema Document
101.CAL*
101.CAL*		XBRL Calculation Linkbase Document
101.LAB*
101.LAB*		XBRL Labels Linkbase Document
101.PRE*
101.PRE*		XBRL Presentation Linkbase Document
101.DEF*
101.DEF*		XBRL Definition Linkbase Document


						COMSTOCK RESOURCES, INC.

Date: ~~November 5, 2015~~August 1, 2016						/s/ M. JAY ALLISON
						M. Jay Allison, Chairman, Chief
						Executive Officer (Principal Executive Officer)

Date: ~~November 5, 2015~~August 1, 2016						/s/ ROLAND O. BURNS
						Roland O. Burns, President, Chief Financial
						Officer and Secretary (Principal Financial and Accounting Officer)