Comstock Resources, Inc. and its subsidiaries are engaged in the acquisition, exploration, development and production of oil and natural gas. The Company's operations are primarily focused in Texas, Louisiana and North Dakota. The consolidated financial statements include the accounts of Comstock Resources, Inc. and its wholly owned or controlled subsidiaries (collectively, "Comstock" or the "Company"). All significant intercompany accounts and transactions have been eliminated in consolidation. The Company accounts for its undivided interest in oil and gas properties using the proportionate consolidation method, whereby its share of assets, liabilities, revenues and expenses are included in its financial statements. Net income (loss) and comprehensive income (loss) are the same in all periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed. Certain amounts in prior periods have been reclassified to conform with current period presentation.

On August 14, 2018, Arkoma Drilling, L.P. and Williston Drilling, L.P. (collectively, the "Jones Partnerships") contributed certain oil and gas properties in North Dakota and Montana (the "Bakken Shale Properties") in exchange for 88,571,429 newly issued shares of common stock representing 84% of the Company's then outstanding common stock (the "Jones Contribution"). The Jones Partnerships are wholly-owned and controlled by Dallas businessman Jerry Jones and his children (collectively, the "Jones Group").

The Company assessed the Bakken Shale Properties to determine whether they met the definition of a business under US generally accepted accounting principles, determining that they did not meet the definition of a business. As a result, the Jones Contribution was not accounted for as a business combination. Upon the issuance of the shares of Comstock common stock, the Jones Group obtained control over Comstock through their ownership of the Jones Partnerships. Through the Jones Partnerships, the Jones Group owns a majority of the voting common stock as well as the ability to control the composition of the majority of the board of directors of Comstock. As a result of the change of control that occurred upon the issuance of the common stock, the Jones Group controls Comstock and, thereby, continues to control the Bakken Shale Properties.

Accordingly, the basis of the Bakken Shale Properties recognized by Comstock is the historical basis of the Jones Group. The historical cost basis of the Bakken Shale properties contributed was $397.6 million, which was comprised of $554.3 million of capitalized costs less $156.7 million of accumulated depletion, depreciation and amortization. The change in control of Comstock resulted in a new basis for Comstock and the Company elected to apply pushdown accounting pursuant to ASC 805, Business Combinations. The new basis was pushed down to Comstock for financial reporting purposes, resulting in Comstock's assets, liabilities and equity accounts being recognized at fair value upon the closing of the Jones Contribution.

References to "Successor" or "Successor Company" relate to the financial position and results of operations of the Company subsequent to August 13, 2018. Reference to "Predecessor" or "Predecessor Company" relate to the financial position and results of operations of the Company on or prior to August 13, 2018. The Company's consolidated financial statements and related footnotes are presented with a black line division which delineates the lack of comparability between amounts presented after August 13, 2018 and dates prior thereto.

On July 16, 2019, Comstock acquired Covey Park Energy LLC ("Covey Park") for total consideration of $700.0 million of cash, the issuance of Series A Convertible Preferred Stock with a redemption value of $210.0 million, and the issuance of 28,833,000 shares of common stock (the "Covey Park Acquisition"). In addition to the consideration paid, Comstock assumed $625.0 million of Covey Park's 7.5% senior notes, repaid $380.0 million of

Covey Park's then outstanding borrowings under its bank credit facility and redeemed all of Covey Park's preferred equity for $153.4 million. Based on the fair value of the preferred stock issued and the closing price of the Company's common stock of $5.82 per share on July 16, 2019, the transaction was valued at approximately $2.2 billion. Covey Park's operations were focused primarily in the Haynesville/Bossier shale in East Texas and North Louisiana.

Funding for the cash consideration was provided by the sale of 50 million newly issued shares of common stock for $300.0 million and 175,000 shares of newly issued Series B Convertible Preferred Stock for $175.0 million to the Jones Group and by borrowings under Comstock's bank credit facility and cash on hand. Comstock incurred $41.0 million of advisory and legal fees and other acquisition-related costs in connection with the acquisition. These acquisition costs are included in transaction costs in the Company's consolidated statements of operations.

The transaction was accounted for as a business combination, using the acquisition method. The purchase price allocation of the assets acquired and liabilities assumed was finalized in the third quarter of 2020. The following table summarizes the original and final purchase price allocations of the assets acquired and liabilities assumed based on their fair values as of the acquisition date:


	Original Allocation		Measurement Period Adjustments		Final Allocation
	(In thousands)
Consideration:
Cash Paid	$	700,000	$	—	$	700,000
Fair Value of Common Stock Issued	167,808		—		167,808
Fair Value of Series A Preferred Stock Issued	200,000		—		200,000
Total Consideration	1,067,808		—		1,067,808
Liabilities Assumed:
Accounts Payable and Accrued Liabilities	129,622		—		129,622
Derivative Financial Instruments	388		—		388
Other Current Liabilities	9,930		706		10,636
Long Term Debt	826,625		—		826,625
Covey Park Preferred Equity	153,390		—		153,390
Non-current Derivative Financial Instruments	186		—		186
Asset Retirement Obligations	5,374		—		5,374
Deferred Income Taxes	23,466		(1,780)		21,686
Other Non-current Liabilities	9,893		—		9,893
Liabilities Assumed	1,158,874		(1,074)		1,157,800
Total Consideration and Liabilities Assumed	$	2,226,682	$	(1,074)	$	2,225,608
Assets Acquired:
Cash and Cash Equivalents	$	6,131	$	—	$	6,131
Accounts Receivable	86,285		—		86,285
Current Derivative Financial Instruments	51,004		—		51,004
Other Current Assets	5,511		(554)		4,957
Proved Oil and Natural Gas Properties	1,818,413		(520)		1,817,893
Unproved Oil and Natural Gas Properties	237,210		—		237,210
Other Property, Plant and Equipment	2,262		—		2,262
Non-current Derivative Financial Instruments	19,866		—		19,866
Total Assets Acquired	$	2,226,682	$	(1,074)	$	2,225,608

The Series A Convertible Preferred Stock was issued with a face value of $210.0 million. Management retained a third-party valuation firm to assess the fair value of the preferred stock. A yield methodology using Level 2 inputs of the Company's publicly traded debt, including the assumption of Covey Park's 7.5% senior notes, resulted in a fair value of $200.0 million. On May 19, 2020, the Company redeemed the 210,000 outstanding shares of the Series A Convertible Preferred Stock for an aggregate redemption price of $210.0 million plus accrued and unpaid dividends of approximately $2.9 million.

The fair value of the proved and unproved oil and natural gas properties was derived from estimated future discounted net cash flows, a Level 3 measurement, based on existing production curves and timing of development of those properties. The key factors used in deriving the estimated future cash flows include estimated recoverable reserves, production rates, future operating and development costs, and future commodity prices. Key inputs to the valuation included average oil prices of $74.80 per barrel and average natural gas prices of $3.32 per Mcf utilizing a combination of third-party price estimates and management price forecasts as of the acquisition date. The resulting estimated future cash flows from the acquired assets were discounted at rates ranging from 10% - 25% depending on risk characteristics of reserve categories acquired. Management utilized the assistance of an independent reserve firm and internal resources to estimate the fair value of the oil and natural gas properties.

The fair value measurements of long-term debt were estimated based on market prices and represent Level 2 inputs. The fair value measurements of derivative instruments assumed were determined based on fair value measurements consistent with managements valuation methodologies including implied market volatility, contract terms and prices and discount factors as of the close date. These inputs represent Level 2 inputs. The fair values of commodity derivative instruments in an asset position include a measure of counterparty nonperformance risk and the derivative instruments in a liability position include a measure of the Company's own nonperformance risk, each based on the current published credit default swap rates.

The fair value of the asset retirement obligations of $5.4 million is included in the oil and natural gas properties with the corresponding liability in the table above. The fair value was based on a discounted cash flow model that included assumptions of current abandonment costs, inflation rates, discount rates and timing of actual abandonment and restoration activities. Due to the inputs and significant assumptions associated with the estimation of asset retirement obligations, the estimates made by management represent Level 3 inputs.

The pro forma condensed combined financial information for the year ended December 31, 2019 gives effect to the Covey Park Acquisition as if the acquisition had occurred on January 1, 2019. The pro forma condensed combined financial information for year ended December 31, 2018 gives effect to the Covey Park Acquisition and the Jones Contribution as if the transactions had occurred on January 1, 2018. The unaudited pro forma information reflects adjustments for the issuance of the Company's common stock and preferred stock, debt incurred in connection with the transaction, impact of the fair value of properties acquired and related depletion other adjustments the Company believes are reasonable for the pro forma presentation. In addition, the pro forma earnings include acquisition-related costs of $41.0 million for year ended December 31, 2019 and 2018, respectively. The unaudited pro forma results do not reflect any cost savings or other synergies that may arise in the future.

On November 1, 2019, Comstock acquired a privately held company with producing properties and acreage in the Haynesville shale basin in exchange for 4,500,000 newly issued shares of the Company's common stock. The acquisition qualified as a tax-free reorganization whereby the Company acquired carryover of the sellers inside tax basis and was accounted for as an asset acquisition. Based on the closing price of the Company's common stock of $6.85 per share on November 1, 2019, and the recognition of deferred income taxes associated with the acquisition, the transaction was valued at approximately $42.3 million.

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual amounts could differ from those estimates. Changes in the future estimated oil and natural gas reserves or the estimated future cash flows attributable to the reserves that are utilized for impairment analyses could have a significant impact on the future results of operations.

Financial instruments that potentially subject the Company to a concentration of credit risk consist principally of cash and cash equivalents, accounts receivable and derivative financial instruments. The Company places its cash with high credit quality financial institutions and its derivative financial instruments with financial institutions and other firms that management believes have high credit ratings. Substantially all of the Company's accounts receivable are due from either purchasers of oil and gas or participants in oil and gas wells for which the Company serves as the operator. Generally, operators of oil and gas wells have the right to offset future revenues against unpaid charges related to operated wells. Oil and gas sales are generally unsecured. The Company's policy is to assess the collectability of its receivables based upon their age, the credit quality of the purchaser or participant and the potential for revenue offset. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectible. Accordingly, no allowance for doubtful accounts has been provided.

The Company holds or has held certain financial assets and liabilities that are required to be measured at fair value. These include cash and cash equivalents held in bank accounts and derivative financial instruments. 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 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.


	For the Years Ended December 31,
	2019				2020
	Carrying Value		Fair Value		Carrying Value		Fair Value
Assets:	(In thousands)
Commodity-based derivatives (1)	$	89,192	$	89,192	$	9,574	$	9,574
Liabilities:
Commodity-based derivatives (1)	4,442		4,442		49,369		49,369
Bank credit facility (2)	1,250,000		1,250,000		500,000		500,000
7½% senior notes due 2025 (3)	455,768		534,375		473,728		628,691
9¾% senior notes due 2026 (3)	820,057		765,000		1,577,824		1,769,625

(1)The Company's natural gas price swaps and basis swap agreements, its interest rate swap agreements and its crude oil and natural gas price collars are classified as Level 2 and measured at fair value using a market approach using third party pricing services and other active markets or broker quotes that are readily available in the public markets. The Company's natural gas swaption contracts provide the counterparty the right, but not the obligation, to extend terms of an existing swap on a predetermined dates. Due to the subjectivity of the inputs used to value the counterparty rights in the contracts, these contracts are classified as Level 3 in the fair value hierarchy.

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. Acquisition costs for proved oil and gas properties, costs of drilling and equipping productive wells, and costs of unsuccessful development wells are capitalized and amortized on an equivalent unit-of-production basis over the life of the remaining related oil and gas reserves. Equivalent units are determined by converting oil to natural gas at the ratio of one barrel of oil for six thousand cubic feet of natural gas. This conversion ratio is not based on the price of oil or natural gas, and there may be a significant difference in price between an equivalent volume of oil versus natural gas. The estimated future costs of dismantlement, restoration, plugging and abandonment of oil and gas properties and related facilities disposal are capitalized when

asset retirement obligations are incurred and amortized as part of depreciation, depletion and amortization expense. Exploration expense includes geological and geophysical expenses and delay rentals related to exploratory oil and gas properties, costs of unsuccessful exploratory drilling and impairments of unproved properties. As of December 31, 2019 and 2020, the unproved properties primarily relate to future drilling locations that were not included in proved undeveloped reserves. Most of these future drilling locations are located on acreage where the reservoir is known to be productive but have been excluded from proved reserves due to uncertainty on whether the wells would be drilled within the next five years as required by SEC rules in order to be included in proved reserves. The costs of unproved properties are transferred to proved oil and gas properties when they are either drilled or they are reflected in proved undeveloped reserves and amortized on an equivalent unit-of-production basis. Costs associated with unevaluated exploratory acreage are periodically assessed for impairment on a property by property basis, and any impairment in value is included in exploration expense. Exploratory drilling costs are initially capitalized as unproved property but charged to expense if and when the well is determined not to have found commercial proved oil and gas reserves. Exploratory drilling costs are evaluated within a one-year period after the completion of drilling.

The Company assesses the need for an impairment of the costs capitalized for its proved oil and gas properties when events or changes in circumstances, such as a significant drop in commodity prices, indicate that the Company may not be able to recover its capitalized costs. If impairment is indicated based on undiscounted expected future cash flows attributable to the property, then a provision for impairment is recognized to the extent that net capitalized costs exceed the estimated fair value of the property. 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. Significant Level 3 assumptions associated with the calculation of discounted future cash flows included in the cash flow model include management's outlook for oil and natural gas prices, future oil and natural gas production, production costs, capital expenditures, and the total proved and risk-adjusted probable oil and natural gas reserves expected to be recovered. Management's oil and natural gas price outlook is developed based on third-party longer-term price forecasts as of each measurement date. The expected future net cash flows are discounted using an appropriate discount rate in determining a property's fair value. The oil and natural gas prices used for determining asset impairments will generally differ from those used in the standardized measure of discounted future net cash flows because the standardized measure requires the use of an average price based on the first day of each month of the preceding year. Unproved properties are evaluated for impairment based upon the results of drilling, planned future drilling and the terms of the oil and gas leases.

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

The Company is not required to amortize goodwill as a charge to earnings; however, the Company is required to conduct an annual review of goodwill for impairment. The Company performs annual assessment of goodwill on October 1st of each year. If the carrying value of goodwill exceeds the fair value, an impairment charge would be recorded for the difference between fair value and carrying value. The Company performed its quantitative assessment of goodwill as of October 1, 2020 and determined there was no indication of impairment.

The Company had right-of-use lease assets of $3.5 million and $3.0 million as of December 31, 2019 and 2020, respectively, related to its corporate office lease, certain office equipment and leased vehicles used in oil and gas operations with corresponding short-term and long-term liabilities. The value of the lease assets and liabilities are determined based upon discounted future minimum cash flows contained within each of the respective contracts. The Company determines if contracts contain a lease at inception of the contract. To the extent that contract terms representing a lease are identified, leases are identified as being either an operating lease or a finance-type lease. Comstock currently has no finance-type leases. Right-of-use lease assets representing the Company's right to use an underlying asset for the lease term and the related lease liabilities represent our obligation to make lease payments under the terms of the contracts. Short-term leases that have an initial term of one year or less are not capitalized; however, amounts paid for those leases are included as part of its lease cost disclosures. Short-term lease costs exclude expenses related to leases with a lease term of one month or less.

Comstock contracts for a variety of equipment used in its oil and natural gas exploration and development operations. Contract terms for this equipment vary broadly, including the contract duration, pricing, scope of services included along with the equipment, cancellation terms, and rights of substitution, among others. The Company's drilling operations routinely change due to changes in oil and natural gas prices, demand for oil and natural gas, and the overall operating and economic environment. Comstock accordingly manages the terms of its contracts for drilling rigs so as to allow for maximum flexibility in responding to these changing conditions. The Company's rig contracts are presently either for periods of less than one year, or they are on terms that provide for cancellation with 45 days advance notice without a specified expiration date. Accordingly, the Company has elected not to recognize right-of-use lease assets for these rig contracts. The costs associated with drilling rig operations are accounted for under the successful efforts method, which generally require that these costs be capitalized as part of our proved oil and natural gas properties on our balance sheet unless they are incurred on exploration wells that are unsuccessful, in which case they are charged to exploration expense.

As of December 31, 2019 and 2020, the operating leases had a weighted average remaining term of 1.96 years and 1.54 years, respectively, and the weighted-average discount rate used to determine the present value of future operating lease payments was 5.0% and 4.3%, respectively. The maturities of Comstock's operating lease obligations are as follows:

The Company's asset retirement obligations relate to future plugging and abandonment costs of its oil and gas properties and related facilities disposal. The Company records a liability in the period in which an asset retirement obligation is incurred, in an amount equal to the estimated fair value of the obligation that is capitalized. Thereafter, this liability is accreted up to the final retirement cost. Accretion of the discount is included as part of depreciation, depletion and amortization in the accompanying consolidated statements of operations.


	Year Ended December 31,
	2019		2020
	(In thousands)
Reserve for future abandonment costs at beginning of the year	$	5,136	$	18,151
Wells acquired	5,700		—
New wells placed on production	516		733
Changes in estimates and timing	6,333		(699)
Liabilities settled	(57)		(80)
Asset divestitures	(45)		—
Accretion expense	568		1,185
Reserve for future abandonment costs at end of the year	$	18,151	$	19,290

The Company has stock-based employee compensation plans under which stock awards, comprised primarily of restricted stock and performance share units, are issued to employees and non-employee directors. The Company follows the fair value-based method in accounting for equity-based compensation. Under the fair value based method, compensation cost is measured at the grant date based on the fair value of the award and is recognized on a straight-line basis over the award vesting period.

In the Predecessor Period January 1, 2018 through August 13, 2018 the Company had three major purchasers of its oil and gas production that accounted for 33%, 22% and 20% of its total oil and gas sales. During the Successor Period August 14, 2018 through December 31, 2018, the Company had two major purchasers of its oil and gas production that accounted for 32% and 18% of its total oil and natural gas sales. In 2019, the Company had three major purchasers of its oil and gas production that accounted for 19%, 16% and 12% of its total oil and gas sales. In 2020, the Company had four major purchasers of its oil and gas production that accounted for 19%, 15%, 15% and 10% of its total oil and gas sales. The loss of any of these purchasers would not have a material adverse effect on the Company as there is an available market for its oil and natural gas production from other purchasers.

Comstock produces oil and natural gas and reports revenues separately for each of these two primary products in its statements of operations. Revenues are recognized upon the transfer of produced volumes to the Company's customers, who take control of the volumes and receive all the benefits of ownership upon delivery at designated sales points. Payment is reasonably assured upon delivery of production. All sales are subject to contracts that have commercial substance, contain specific pricing terms, and define the enforceable rights and obligations of both parties. These contracts typically provide for cash settlement within 25 days following each production month and are cancellable upon 30 days' notice by either party for oil and vary for natural gas based upon the terms set out in the confirmations between both parties. Prices for sales of oil and natural gas are generally based upon terms that are common in the oil and gas industry, including index or spot prices, location and quality differentials, as well as market supply and demand conditions. As a result, prices for oil and natural gas routinely fluctuate based on changes in these factors. Each unit of production (barrel of crude oil and thousand cubic feet of natural gas) represents a separate performance obligation under the Company's contracts since each unit has economic benefit on its own and each is priced separately according to the terms of the contracts.

Comstock has elected to exclude all taxes from the measurement of transaction prices, and its revenues are reported net of royalties and exclude revenue interests owned by others because the Company acts as an agent when selling crude oil and natural gas, on behalf of royalty owners and working interest owners. Revenue is recorded in the month of production based on an estimate of the Company's share of volumes produced and prices realized. The Company recognizes any differences between estimates and actual amounts received in the month when payment is received. Historically, differences between estimated revenues and actual revenue received have not been significant. The amount of oil or natural gas sold may differ from the amount to which the Company is entitled based on its revenue interests in the properties. The Company did not have any significant imbalance positions at December 31, 2019 or 2020. Sales of oil and natural gas generally occur at or near the wellhead. When sales of oil and gas occur at locations other than the wellhead, the Company accounts for costs incurred to transport the production to the delivery point as gathering and transportation expenses. The Company has recognized accounts receivable of $120.1 million and $125.0 million as of December 31, 2019 and 2020, respectively, from customers for contracts where performance obligations have been satisfied and an unconditional right to consideration exists.

General and administrative expenses are reported net of reimbursements of overhead costs that are received from working interest owners of the oil and gas properties operated by the Company of $8.5 million, $4.5 million, $16.8 million and $24.7 million for the Predecessor Period from January 1, 2018 through August 13, 2018, for the Successor Period from August 14, 2018 through December 31, 2018 and for the years ended December 31, 2019 and 2020, respectively.

The Company accounts for income taxes using the asset and liability method, whereby deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of assets and liabilities and their respective tax basis, as well as the tax consequences attributable to the future utilization of existing net operating loss and other carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences and carryforwards are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that the change in rate is enacted.

Unvested restricted stock containing nonforfeitable rights to dividends are included in common stock outstanding and are considered to be participating securities and included in the computation of basic and diluted earnings per share pursuant to the two-class method. Weighted average shares of unvested restricted stock included in common stock outstanding were as follows:

Performance share units ("PSUs") represent the right to receive a number of shares of the Company's common stock that may range from zero to up to two times the number of PSUs granted on the award date based on the achievement of certain performance measures during a performance period. The number of potentially dilutive shares related to PSUs is based on the number of shares, if any, which would be issuable at the end of the respective period, assuming that date was the end of the performance period. The treasury stock method is used to measure the dilutive effect of PSUs.

For the year ended December 31, 2019, the Series A and Series B Convertible Preferred Stock issued in connection with the Covey Park Acquisition were convertible into in the aggregate 96,250,000 shares of common stock. For the year ended December 31, 2020, the Series A Convertible Preferred Stock was convertible into 52,500,000 shares of common stock prior to their redemption on May 19, 2020 and the Series B Convertible Preferred Stock is convertible into an aggregate of 43,750,000 shares of common stock at a conversion price of $4.00 per share. The dilutive effect of preferred stock is computed using the if-converted method as if conversion of the preferred shares had occurred at the earlier of the date of issuance or the beginning of the period.


	Predecessor		Successor
	For the Period from January 1, 2018 through August 13, 2018		For the Period from August 14, 2018 through December 31, 2018		Year Ended December 31, 2019		Year Ended December 31, 2020
	(In thousands)
Weighted average PSUs	476		328		—		632
Weighted average grant date fair value per unit	$	13.83	$	12.93	$	—	$	9.33
Weighted average convertible preferred stock	—		—		—		63,832
Weighted average warrants for common stock	142		—		—		—
Weighted average exercise price per share	$	0.01	$	—	$	—	$	—
Weighted average contingently convertible shares	39,819		—		—		—
Weighted average conversion price per share	$	12.32	$	—	$	—	$	—


	Predecessor		Successor
	For the Period January 1, 2018 through August 13, 2018		For the Period from August 14, 2018 through December 31, 2018		Year Ended December 31, 2019		Year Ended December 31, 2020
	(In thousands, except per share amounts)
Net income (loss) attributable to common stockholders	$	(92,754)	$	64,122	$	74,474	$	(83,413)
Income allocable to unvested restricted shares	—		(248)		(356)		—
Basic net income (loss) attributable to common stockholders	$	(92,754)	$	63,874	$	74,118	$	(83,413)
Income allocable to convertible preferred stock	—		—		22,415		—
Diluted net income (loss) attributable to common stockholders	$	(92,754)	$	63,874	$	96,533	$	(83,413)

Basic weighted average shares outstanding	15,262		105,453		142,750		215,194
Effect of dilutive securities:
Performance stock units	—		—		63		—
Convertible preferred stock	—		—		44,565		—
Stock warrants	—		6		—		—
Diluted weighted average shares outstanding	15,262		105,459		187,378		215,194

Basic income (loss) per share	$	(6.08)	$	0.61	$	0.52	$	(0.39)
Diluted income (loss) per share	$	(6.08)	$	0.61	$	0.52	$	(0.39)


	Predecessor		Successor
	For the Period from January 1, 2018 through August 13, 2018		For the Period from August 14, 2018 through December 31, 2018		Year Ended December 31, 2019		Year Ended December 31, 2020
	(In thousands)
Cash payments for:
Interest payments	$	36,187	$	8,042	$	149,039	$	228,555
Income tax (payments) refunds	$	(2)	$	—	$	(2)	$	10,218
Non-cash investing activities include:
Increase (decrease) in accrued capital expenditures	$	(3,255)	$	15,301	$	24,273	$	(17,234)
Liabilities assumed in exchange for right-of-use lease assets	$	—	$	—	$	5,372	$	1,761
Non-cash investing and financing activities related to acquisitions
Issuance of common stock	$	—	$	760,829	$	198,633	$	—
Issuance of Series A Convertible Preferred Stock	$	—	$	—	$	200,000	$	—
Assumed 7½% senior notes	$	—	$	—	$	446,625	$	—
Acquired working capital	$	—	$	36,351	$	41,365	$	520
Non-cash financing activities include:
Retirement of debt in exchange for common stock	$	—	$	—	$	—	$	(4,151)
Issuance of common stock in exchange for debt	$	—	$	—	$	—	$	5,012

In January 2017, the FASB issued Accounting Standards Update No. 2017-4 (ASU 2017-4) "Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment." ASU 2017-4 eliminates step two of the goodwill impairment test and specifies that goodwill impairment should be measured by comparing the fair value of a reporting unit with its carrying amount. ASU 2017-4 was effective for annual or interim goodwill impairment tests performed in fiscal years beginning after December 15, 2019 and early adoption was permitted. We implemented ASU 2017-4 when we performed our annual impairment assessment during the fourth quarter of 2020 and it did not have a significant effect on our results of operations, liquidity or financial position.

In June 2016, The FASB issued Accounting Standards Update ASU No. 2016-13 ("ASU 2016-13") that amends guidance on reporting credit losses for trade receivables, net investments in leases, debt securities, loans and certain other instruments. ASU 2016-13 requires the use of a forward-looking expected loss model as opposed to existing incurred loss recognition. The update was effective for us beginning in 2020. The guidance required a cumulative-effect adjustment to the statement of financial position as of the beginning of the first reporting period in which the standard is effective. We implemented ASU 2016-13 and concluded there was no cumulative-effect adjustment required as of January 1, 2020. The implementation of ASU 2016-13 did not have a material impact on our results of operations, financial position and financial disclosures.