GDP Goodrich Petroleum Corporation

 

NOTE 1—Description of Business and Significant Accounting Policies

 

Goodrich Petroleum Corporation (“Goodrich” and, together with its subsidiary, Goodrich Petroleum Company, L.L.C. (the “Subsidiary”), “we,” “our,” or the “Company”) is an independent oil and natural gas company engaged in the exploration, development and production of oil and natural gas on properties primarily in (i) Northwest Louisiana and East Texas, which includes the Haynesville Shale Trend, (ii) Southwest Mississippi and Southeast Louisiana, which includes the Tuscaloosa Marine Shale Trend (“TMS”), and (iii) South Texas, which includes the Eagle Ford Shale Trend.

 

Basis of Presentation

 

The consolidated financial statements of the Company included in this Quarterly Report on Form 10-Q have been prepared, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission and accordingly, certain information normally included in financial statements prepared in accordance with United States Generally Accepted Accounting Principles (“US GAAP”) has been condensed or omitted. This information should be read in conjunction with our consolidated financial statements and notes contained in our Annual Report on Form 10-K for the year ended December 31, 2019. Operating results for the three and six months ended June 30, 2020 are not necessarily indicative of the results that may be expected for the full year or for any interim period.

 

The impact of the COVID-19 pandemic and related economic, business and market disruptions is both on-going and continuing to evolve, and its future effects are uncertain. The Company has seen impacts related to COVID-19 on oil price fluctuations due to market uncertainty. The full impact of COVID-19 and related market impacts on the Company will depend on many factors, many of which are beyond management's control and knowledge. It is therefore difficult for management to assess or predict with precision the broad future effect of this health crisis on the global economy, the energy industry or the Company. As additional information becomes available, events or circumstances change and strategic operational decisions are made by management, adjustments may be required which could have a material adverse impact on the Company's consolidated financial position, results of operations and cash flows.

 

Restatement of Previously Issued Unaudited Consolidated Financial Statements

 

The Company has restated its unaudited consolidated financial statements as of and for the three and six months ended June 30, 2020 to correct an error in a component of the estimated PV-10 of its reserves, which impacted the full cost ceiling impairment of oil and natural gas properties. This error as of June 30, 2020 was identified in the course of preparing the Company's consolidated financial statements for the quarter ended September 30, 2020.

 

The following table presents the effect of the error correction discussed above on all affected line items of our previously issued consolidated balance sheets as of June 30, 2020.

 

Consolidated Balance Sheets
		June 30, 2020
		As Reported				Adjustments				As Restated
		(In thousands)
Accumulated depletion, depreciation, amortization and impairment		$	(126,590	)		$	(7,283	)		$	(133,873	)
Net property and equipment			209,399				(7,283	)			202,116
TOTAL ASSETS		$	227,413			$	(7,283	)		$	220,130
Accumulated earnings (deficit)			(9,887	)			(7,283	)			(17,170	)
Total stockholders’ equity			74,397				(7,283	)			67,114
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY		$	227,413				(7,283	)		$	220,130

 

The following tables present the effect of the error correction discussed above on all affected line items of our previously issued consolidated statements of operations for the three and six months ended June 30, 2020.

 

Consolidated Statements of Operations
		Three Months Ended June 30, 2020
		As Reported				Adjustments				As Restated
		(In thousands)
Impairment of oil and natural gas properties		$	6,847			$	7,283			$	14,130
Total operating expenses			32,742				7,283				40,025
Operating income (loss)			(12,268	)			(7,283	)			(19,551	)
Income (loss) before income taxes			(15,658	)			(7,283	)			(22,941	)
Net income (loss)		$	(15,658	)		$	(7,283	)		$	(22,941	)
PER COMMON SHARE
Net income (loss) per common share - basic		$	(1.25	)		$	(0.58	)		$	(1.83	)
Net income (loss) per common share - diluted		$	(1.25	)		$	(0.58	)		$	(1.83	)

 

 

		Six Months Ended June 30, 2020
		As Reported				Adjustments				As Restated
		(In thousands)
Impairment of oil and natural gas properties		$	6,847			$	7,283			$	14,130
Total operating expenses			59,997				7,283				67,280
Operating income (loss)			(16,537	)			(7,283	)			(23,820	)
Income (loss) before income taxes			(12,622	)			(7,283	)			(19,905	)
Net income (loss)		$	(12,622	)			(7,283	)		$	(19,905	)
PER COMMON SHARE
Net income (loss) per common share - basic		$	(1.01	)		$	(0.58	)		$	(1.59	)
Net income (loss) per common share - diluted		$	(1.01	)		$	(0.58	)		$	(1.59	)

 

The following table presents the effect of the error correction discussed above on all affected line items of our previously issued consolidated statements of cash flows for the six months ended June 30, 2020.

 

Consolidated Statements of Cash Flows
		Six Months Ended June 30, 2020
		As Reported				Adjustments				As Restated
		(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)		$	(12,622	)		$	(7,283	)		$	(19,905	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Impairment of oil and natural gas properties			6,847				7,283				14,130

 

The following tables present the effect of the error correction discussed above on all affected line items of our previously issued consolidated statements of stockholders' equity (in thousands) for the three months ended June 30, 2020.

 

Consolidated Statements of Stockholders' Equity
		Accumulated Earnings (Deficit)
		As Reported				Adjustments				As Restated
Net loss		$	(15,658	)		$	(7,283	)		$	(22,941	)
Balance at June 30, 2020			(9,887	)			(7,283	)			(17,170	)

 

		Total Stockholders' Equity
		As Reported				Adjustments				As Restated
Net loss		$	(15,658	)		$	(7,283	)		$	(22,941	)
Balance at June 30, 2020			74,397			$	(7,283	)			67,114

 

Principles of Consolidation—The consolidated financial statements include the financial statements of the Company and the Subsidiary. Intercompany balances and transactions have been eliminated in consolidation. The consolidated financial statements reflect all normal recurring adjustments that, in the opinion of management, are necessary for a fair presentation. Certain data in prior periods’ financial statements have been adjusted to conform to the presentation of the current period. We have evaluated subsequent events through the date of this filing.

 

Use of Estimates— Our management has made a number of estimates and assumptions relating to the reporting of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities to prepare these consolidated financial statements in conformity with US GAAP.

 

Cash and Cash Equivalents—Cash and cash equivalents includes cash on hand, demand deposit accounts and temporary cash investments with maturities of ninety days or less at the date of purchase.

 

Accounts Payable—Accounts payable consisted of the following amounts as of June 30, 2020 and December 31, 2019:

 

(In thousands)		June 30, 2020				December 31, 2019
Trade payables		$	13,583			$	11,461
Revenue payables			12,186				14,483
Prepayments from partners			488				-
Miscellaneous payables			377				404
Total Accounts payable		$	26,634			$	26,348

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

Accrued Liabilities—Accrued liabilities consisted of the following amounts as of June 30, 2020 and December 31, 2019:

 

(In thousands)		June 30, 2020				December 31, 2019
Accrued capital expenditures		$	1,117			$	6,175
Accrued lease operating expense			962				989
Accrued production and other taxes			970				430
Accrued transportation and gathering			2,445				2,258
Accrued performance bonus			1,907				4,642
Accrued interest			209				208
Accrued office lease			1,521				1,414
Accrued general and administrative expense and other			403				499
Total Accrued liabilities		$	9,534			$	16,615

 

Inventory –Inventory consists of casing and tubulars that are expected to be used in our capital drilling program. Inventory is carried on the Consolidated Balance Sheets at the lower of cost or market.

 

Property and Equipment—Under US GAAP, two acceptable methods of accounting for oil and natural gas properties are allowed. These are the Successful Efforts Method and the Full Cost Method. Entities engaged in the production of oil and natural gas have the option of selecting either method for application in the accounting for their properties. The principal differences between the two methods are in the treatment of exploration costs, the computation of depreciation, depletion and amortization (“DD&A”) expense and the assessment of impairment of oil and natural gas properties. We have elected to adopt the Full Cost Method of accounting. We believe that the true cost of developing a “portfolio” of reserves should reflect both successful and unsuccessful attempts at exploration and production. Application of the Full Cost Method better reflects the true economics of exploring for and developing our oil and gas reserves.

 

Under the Full Cost Method, we capitalize all costs associated with acquisitions, exploration, development and estimated abandonment costs. We capitalize internal costs that can be directly identified with the acquisition of leasehold, as well as drilling and completion activities, but do not include any costs related to production, general corporate overhead or similar activities. Unevaluated property costs are excluded from the amortization base until we make a determination as to the existence of proved reserves on the respective property or impairment. We review our unevaluated properties at the end of each quarter to determine whether the costs should be reclassified to proved oil and natural gas properties and thereby subject to DD&A and the full cost ceiling test. For the three months ended June 30, 2020 and 2019, we transferred less than $0.1 million and $0.1 million, respectively, from unevaluated properties to proved oil and natural gas properties. For the six months ended June 30, 2020 and 2019, we transferred less than $0.1 million and $0.2 million, respectively, from unevaluated properties to proved oil and natural gas properties. Our sales of oil and natural gas properties are accounted for as adjustments to net proved oil and natural gas properties with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves.

 

Under the Full Cost Method, we amortize our investment in oil and natural gas properties through DD&A expense using the units of production method. An amortization rate is calculated based on total proved reserves converted to equivalent thousand cubic feet of natural gas (“Mcfe”) as the denominator and the net book value of the evaluated oil and gas asset together with the estimated future development cost of the proved undeveloped reserves as the numerator. The rate calculated per Mcfe is applied against the periods' production also converted to Mcfe to arrive at the periods' DD&A expense.

 

Depreciation of furniture, fixtures and equipment, consisting of office furniture, computer hardware and software and leasehold improvements, is computed using the straight-line method over their estimated useful lives, which vary from three to five years.

 

Full Cost Ceiling Test—The Full Cost Method requires that at the conclusion of each financial reporting period, the present value of estimated future net cash flows from proved reserves (adjusted for hedges and excluding cash flows related to estimated abandonment costs), be compared to the net capitalized costs of proved oil and natural gas properties, net of related deferred taxes. This comparison is referred to as a “ceiling test.” If the net capitalized costs of proved oil and natural gas properties exceed the estimated discounted future net cash flows from proved reserves, we are required to write-down the value of our oil and natural gas properties to the value of the discounted cash flows. Estimated future net cash flows from proved reserves are calculated based on a 12-month average pricing assumption.

 

The Full Cost Ceiling Test performed as of June 30, 2020 and 2019 resulted in $14.1 million and zero write-down of the oil and gas properties, respectively. The low commodity prices experienced in the first half of 2020 lowered the latest 12-month average price used in the ceiling test resulting in the present value of future net cash flows being lower than our capitalized cost. We may continue to be required to impair our oil and gas properties in the future, if commodity prices do not recover to previous period levels.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

Fair Value Measurement—Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The fair value of an asset should reflect its highest and best use by market participants, whether in-use or an in-exchange valuation premise. The fair value of a liability should reflect the risk of non-performance, which includes, among other things, our credit risk.

 

We use various methods, including the income approach and market approach, to determine the fair values of our financial instruments that are measured at fair value on a recurring basis, which depend on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. For some of our instruments, the fair value is calculated based on directly observable market data or data available for similar instruments in similar markets. For other instruments, the fair value may be calculated based on these inputs as well as other assumptions related to estimates of future settlements of these instruments. We separate our financial instruments into three levels (levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine the fair value of our instruments. Our assessment of an instrument can change over time based on the maturity or liquidity of the instrument, which could result in a change in the classification of the instruments between levels.

 

Each of these levels and our corresponding instruments classified by level are further described below:

 

•

Level 1 Inputs— unadjusted quoted market prices in active markets for identical assets or liabilities. We have no Level 1 instruments;

•

Level 2 Inputs— quotes that are derived principally from or corroborated by observable market data. Included in this level are our senior credit facilities and commodity derivatives whose fair values are based on third-party quotes or available interest rate information and commodity pricing data obtained from third party pricing sources and our creditworthiness or that of our counter-parties; and

•

Level 3 Inputs— unobservable inputs for the asset or liability, such as discounted cash flow models or valuations, based on our various assumptions and future commodity prices. Included in this level would be our initial measurement of asset retirement obligations.

 

As of June 30, 2020 and December 31, 2019, the carrying amounts of our cash and cash equivalents, trade receivables and payables represented fair value because of the short-term nature of these instruments.

 

Asset Retirement Obligations—Asset retirement obligations are related to the abandonment and site restoration requirements that result from the exploration and development of our oil and natural gas properties. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense is included in “Depreciation, depletion and amortization” on our Consolidated Statements of Operations. See Note 3.

 

The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the initial measurement of the asset retirement obligations was classified as Level 3 in the fair value hierarchy.

 

Revenue Recognition—Oil and natural gas revenues are generally recognized upon delivery of our produced oil and natural gas volumes to our customers. We record revenue in the month our production is delivered to the purchaser. However, settlement statements and payments for our oil and natural gas sales may not be received for up to 60 days after the date production is delivered, and as a result, we are required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. We record a liability or an asset for natural gas balancing when we have sold more or less than our working interest share of natural gas production, respectively. As of June 30, 2020 and December 31, 2019, the net liability for natural gas balancing was immaterial. Differences between actual production and net working interest volumes are routinely adjusted. See Note 2.

 

Derivative Instruments—We use derivative instruments such as futures, forwards, swaps, collars, and options for purposes of hedging our exposure to fluctuations in the price of crude oil and natural gas and hedging our exposure to changing interest rates. Accounting standards related to derivative instruments and hedging activities require that all derivative instruments subject to the requirements of those standards be measured at fair value and recognized as assets or liabilities in the balance sheet. We offset the fair value of our asset and liability positions with the same counter-party for each commodity type. Changes in fair value are required to be recognized in earnings unless specific hedge accounting criteria are met. All of our realized gain or losses on our derivative contracts are the result of cash settlements. We have not designated any of our derivative contracts as hedges; accordingly, changes in fair value are reflected in earnings. See Note 8.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

Income Taxes—We account for income taxes, as required, under the liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carry-forwards. 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 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 includes the enactment date. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized.

 

We recognize, as required, the financial statement benefit of an uncertain tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit. For tax positions meeting the more likely-than-not threshold, the amount recognized in the financial statements is the largest benefit that has a greater than 50 percent likelihood of being realized upon ultimate settlement with the relevant tax authority. See Note 7.

 

Net Income or Net Loss Per Common Share—Basic income (loss) per common share is computed by dividing net income (loss) applicable to common stock for each reporting period by the weighted-average shares of common stock outstanding during the period. Diluted income (loss) per common share is computed by dividing net income (loss) applicable to common stock for each reporting period by the weighted average shares of common stock outstanding during the period, plus the effects of potentially dilutive restricted stock calculated using the treasury stock method and the potential dilutive effect of the conversion of convertible securities, such as warrants and convertible notes, into shares of our common stock. See Note 6.

 

Commitments and Contingencies—Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines and penalties, and other sources are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. Recoveries from third parties, when probable of realization, are separately recorded and are not offset against the related environmental liability. See Note 9.

 

Share-Based Compensation—We account for our share-based transactions using the fair value as of the grant date and recognize compensation expense over the requisite service period.

 

Guarantee—As of June 30, 2020, Goodrich Petroleum Company, LLC, the wholly owned subsidiary of Goodrich Petroleum Corporation, was the Subsidiary Guarantor of our New 2L Notes (as defined below). The parent company has no independent assets or operations, the guarantee is full and unconditional, and the parent has no subsidiaries other than Goodrich Petroleum Company, LLC.

 

Debt Issuance Cost—The Company records debt issuance costs associated with its New 2L Notes (and previously with its Convertible Second Lien Notes, both as defined below) as a contra balance to long term debt, net in our Consolidated Balance Sheets, which is amortized straight-line over the life of the respective notes. Debt issuance costs associated with our revolving credit facility debt are recorded in other assets in our Consolidated Balance Sheets, which is amortized straight-line over the life of such debt.

 

New Accounting Pronouncements

 

In December 2019, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. The amendments in this ASU adds new guidance to simplify accounting for income taxes, changes the accounting for certain income tax transactions and makes minor improvements to the codification. For public entities, the amendments in this ASU are effective for fiscal periods beginning after December 15, 2020, including interim periods therein. We are evaluating the expected impact these amendments will have on our consolidated financial statements; however, we do not expect a material impact from the adoption of this ASU.

 

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting. The amendments is this ASU provide optional guidance for a limited period of time to ease the potential burden in accounting for (or recognizing the effects of) reference rate reform on financial reporting. The amendments in this ASU provide optional expedients and exceptions for applying US GAAP to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met. The amendments in this Update apply only to contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. The expedients and exceptions provided by this ASU do not apply to contract modifications made and hedging relationships entered into or evaluated after December 31, 2022, except for hedging relationships existing as of December 31, 2022, that an entity has elected certain optional expedients for and that are retained through the end of the hedging relationship. We are evaluating the expected impact these amendments and reference rate reform will have on our consolidated financial statements and various contracts.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

 

NOTE 2—Revenue Recognition

 

In accordance with Accounting Standards Codification Topic 606, revenue is generally recognized upon delivery of our produced oil and natural gas volumes to our customers. Our customer sales contracts include oil and natural gas sales. Under Topic 606, each unit (Mcf or barrel) of commodity product represents a separate performance obligation which is sold at variable prices, determinable on a monthly basis. The pricing provisions of our contracts are primarily tied to a market index with certain adjustments based on factors such as delivery, product quality and prevailing supply and demand conditions in the geographic areas in which we operate. We allocate the transaction price to each performance obligation and recognize revenue upon delivery of the commodity product when the customer obtains control. Control of our produced natural gas volumes passes to our customers at specific metered points indicated in our natural gas contracts. Similarly, control of our produced oil volumes passes to our customers when the oil is measured either by a trucking oil ticket or by a meter when entering an oil pipeline. The Company has no control over the commodities after those points and the measurement at those points dictates the amount on which the customer's payment is based. Our oil and natural gas revenue streams include volumes burdened by royalty and non-operated working interests. Our revenues are recorded and presented on our financial statements net of the royalty and non-operated working interests. Our revenue stream does not include any payments for services or ancillary items other than sale of oil and natural gas.

 

We record revenue in the month our production is delivered to the purchaser. However, settlement statements and payments for our oil and natural gas sales may not be received for up to 60 days after the date production is delivered, and as a result, we are required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. We record any differences, which historically have not been significant, between the actual amounts ultimately received and the original estimates in the period they become finalized. As of June 30, 2020 and December 31, 2019, receivables from contracts with customers were $7.6 million and $11.3 million, respectively.

 

The following table presents our oil and natural gas revenues disaggregated by revenue source and by operated and non-operated properties for the three and six months ended June 30, 2020 and 2019:

 

		Three Months Ended June 30, 2020																Six Months Ended June 30, 2020
(In thousands)		Oil Revenue				Gas Revenue				NGL Revenue				Total Oil and Natural Gas Revenues				Oil Revenue				Gas Revenue				NGL Revenue				Total Oil and Natural Gas Revenues
Operated		$	1,029			$	15,353			$	-			$	16,382			$	2,750			$	34,491			$	-			$	37,241
Non-operated			408				3,680				1				4,089				501				5,708				4				6,213
Total oil and natural gas revenues		$	1,437			$	19,033			$	1			$	20,471			$	3,251			$	40,199			$	4			$	43,454

 

		Three Months Ended June 30, 2019																Six Months Ended June 30, 2019
(In thousands)		Oil Revenue				Gas Revenue				NGL Revenue				Total Oil and Natural Gas Revenues				Oil Revenue				Gas Revenue				NGL Revenue				Total Oil and Natural Gas Revenues
Operated		$	2,805			$	25,163			$	-			$	27,968			$	5,516			$	45,337			$	-			$	50,853
Non-operated			139				3,775				4				3,918				214				9,957				8				10,179
Total oil and natural gas revenues		$	2,944			$	28,938			$	4			$	31,886			$	5,730			$	55,294			$	8			$	61,032

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

 

 

NOTE 4—Debt

 

Debt consisted of the following balances as of June 30, 2020 and December 31, 2019 (in thousands):

 

		June 30, 2020								December 31, 2019
		Principal				Carrying Amount				Principal				Carrying Amount
2019 Senior Credit Facility (1)		$	95,400			$	95,400			$	92,900			$	92,900
New 2L Notes (2)			13,859				12,525				12,969				11,535
Total debt		$	109,259			$	107,925			$	105,869			$	104,435

 

(1) The carrying amount for the 2019 Senior Credit Facility represents fair value as it was fully secured.

(2) The debt discount is being amortized using the effective interest rate method based upon a maturity date of May 31, 2022. The principal includes $1.9 million and $1.0 million of paid in-kind interest as of June 30, 2020 and December 31, 2019, respectively. The carrying value includes $1.1 million and $1.1 million of unamortized debt discount and $0.2 million and $0.3 million of unamortized issuance cost as of June 30, 2020 and December 31, 2019, respectively.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

The following table summarizes the total interest expense (contractual interest expense, amortization of debt discount, accretion and financing costs) and the effective interest rate on the liability component of debt for the three and six months ended June 30, 2020 and 2019 (amounts in thousands, except effective interest rates):

 

		Three Months Ended June 30, 2020								Three Months Ended June 30, 2019								Six Months Ended June 30, 2020								Six Months Ended June 30, 2019
		Interest Expense				Effective Interest Rate				Interest Expense				Effective Interest Rate				Interest Expense				Effective Interest Rate				Interest Expense				Effective Interest Rate
2017 Senior Credit Facility		$	-				—	%		$	364				8.2	%		$	-				—	%		$	872				7.2	%
2019 Senior Credit Facility			1,106				4.6	%			695				5.9	%			2,405				5.1	%			695				5.9	%
Convertible Second Lien Notes (1)			-				—	%			2,155				23.9	%			-				—	%			5,304				24.1	%
New 2L Notes (2)			619				20.0	%			184				20.5	%			1,272				21.0	%			184				20.5	%
Total interest expense		$	1,725							$	3,398							$	3,677							$	7,055

 

(1) The Convertible Second Lien Notes had a coupon interest rate of 13.50%; however, the discount recorded due to the convertibility of the notes increased the effective interest rate to 23.9% and 24.1%, respectively, for the three and six months ended June 30, 2019. Interest expense for the three months ended June 30, 2019 included $0.9 million of debt discount amortization and $1.2 million of paid in-kind interest, and interest expense for the six months ended June 30, 2019 included $2.3 million of debt discount amortization and $3.0 million of paid in-kind interest.

(2) The New 2L Notes have a coupon interest rate of 13.50%; however, the discount recorded due to the convertibility of the notes increased the effective interest rate to 19.9% and 20.9%, respectively, for the three and six months ended June 30, 2020 and 20.5% for the three and six months ended June 30, 2019. Interest expense for the three months ended June 30, 2020 included $0.1 million of debt discount amortization and $0.5 million of accrued interest to be paid in-kind, and interest expense for the six months ended June 30, 2020 included $0.3 million of debt discount amortization and $0.9 million of accrued interest to be paid in-kind. Interest expense for the three and six months ended June 30, 2019 included less than $0.1 million of debt discount amortization and $0.1 million of accrued interest to be paid in-kind.

 

2017 Senior Credit Facility

 

On October 17, 2017, the Company entered into the Amended and Restated Senior Secured Revolving Credit Agreement (as amended, the “2017 Credit Agreement”) with the Subsidiary, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, and certain lenders that are party thereto, which provided for revolving loans of up to the borrowing base then in effect (as amended, the “2017 Senior Credit Facility”). The 2017 Senior Credit Facility was set to mature on (a) October 17, 2021 or (b) December 30, 2019, if the Convertible Second Lien Notes had not been voluntarily redeemed, repurchased, refinanced or otherwise retired by December 30, 2019. The maximum credit amount under the 2017 Senior Credit Facility when it was paid off in full on May 14, 2019 was $250.0 million with a borrowing base of $75.0 million.

 

All amounts outstanding under the 2017 Senior Credit Facility bore interest at a rate per annum equal to, at the Company's option, either (i) the alternative base rate plus an applicable margin ranging from 1.75% to 2.75%, depending on the percentage of the borrowing base that was utilized, or (ii) adjusted LIBOR plus an applicable margin ranging from 2.75% to 3.75%, depending on the percentage of the borrowing base that was utilized. Undrawn amounts under the 2017 Senior Credit Facility were subject to a 0.50% commitment fee.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

The obligations under the 2017 Credit Agreement were secured by a first lien security interest in substantially all of the assets of the Company and the Subsidiary.

 

On May 14, 2019, the 2017 Senior Credit Facility was paid off in full and amended, restated and refinanced into the 2019 Senior Credit Facility. In connection with the refinancing, we recorded a $0.2 million loss on early extinguishment of debt related to the remaining unamortized debt issuance costs.

 

2019 Senior Credit Facility

 

On May 14, 2019, the Company entered into a Second Amended and Restated Senior Secured Revolving Credit Agreement (the “2019 Credit Agreement”) among the Company, the Subsidiary, as borrower (in such capacity, the “Borrower”), SunTrust Bank, as administrative agent (the “Administrative Agent”), and certain lenders that are party thereto, which provides for revolving loans of up to the borrowing base then in effect (the “2019 Senior Credit Facility”).

 

The 2019 Senior Credit Facility matures on (a) May 14, 2024 or (b) December 3, 2021, if the New 2L Notes (as defined below) have not been voluntarily redeemed, repurchased, refinanced or otherwise retired by December 3, 2021, which is the date that is 180 days prior to the May 31, 2022 “Maturity Date” of the New 2L Notes. The 2019 Senior Credit Facility provides for a maximum credit amount of $500 million subject to a borrowing base limitation, which was $120 million as of June 30, 2020. The borrowing base is scheduled to be redetermined in March and September of each calendar year, and is subject to additional adjustments from time to time, including for asset sales, elimination or reduction of hedge positions and incurrence of other debt. Additionally, each of the Borrower and the Administrative Agent may request one unscheduled redetermination of the borrowing base between scheduled redeterminations. The amount of the borrowing base is determined by the lenders in their sole discretion and consistent with their oil and gas lending criteria at the time of the relevant redetermination. The Borrower may also request the issuance of letters of credit under the 2019 Credit Agreement in an aggregate amount up to $10 million, which reduce the amount of available borrowings under the borrowing base in the amount of such issued and outstanding letters of credit.

 

All amounts outstanding under the 2019 Senior Credit Facility bear interest at a rate per annum equal to, at the Company’s option, either (i) the alternative base rate plus an applicable margin ranging from 1.50% to 2.50%, depending on the percentage of the borrowing base that is utilized, or (ii) adjusted LIBOR plus an applicable margin from 2.50% to 3.50%, depending on the percentage of the borrowing base that is utilized. Undrawn amounts under the 2019 Senior Credit Facility are subject to a commitment fee ranging from 0.375% to 0.50%, depending on the percentage of the borrowing base that is utilized. To the extent that a payment default exists and is continuing, all amounts outstanding under the 2019 Senior Credit Facility will bear interest at 2.0% per annum above the rate and margin otherwise applicable thereto. As of June 30, 2020, the weighted average interest rate on the borrowings from the 2019 Senior Credit Facility was 3.99%. The obligations under the 2019 Credit Agreement are guaranteed by the Company and secured by a first lien security interest in substantially all of the assets of the Company and the Borrower.

 

The 2019 Credit Agreement contains certain customary representations and warranties, affirmative and negative covenants and events of default. If an event of default occurs and is continuing, the lenders may declare all amounts outstanding under the 2019 Senior Credit Facility to be immediately due and payable.

 

The 2019 Credit Agreement also contains certain financial covenants, including the maintenance of (i) a ratio of Net Funded Debt to EBITDAX not to exceed 4.00 to 1.00 as of the last day of any fiscal quarter, (ii) a current ratio (based on the ratio of current assets to current liabilities as defined in the 2019 Credit Agreement) not to be less than 1.00 to 1.00 and (iii) until no New 2L Notes remain outstanding, a ratio of Total Proved PV-10 attributable to the Company’s and Borrower’s Proved Reserves to Total Secured Debt (net of any Unrestricted Cash not to exceed $10 million) not to be less than 1.50 to 1.00 and minimum liquidity requirements. On May 14, 2019, the Company utilized borrowings under the 2019 Senior Credit Facility to refinance its obligations under the 2017 Senior Credit Facility and to fund the Redemption (as defined below) of the Convertible Second Lien Notes.

 

As of June 30, 2020, the Company had $95.4 million of borrowings outstanding under the 2019 Senior Credit Facility. The Company also had $2.0 million of unamortized debt issuance costs recorded as of June 30, 2020 related to the 2019 Senior Credit Facility.

 

As of June 30, 2020, the Company was in compliance with all covenants within the 2019 Senior Credit Facility.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

Convertible Second Lien Notes

 

In October 2016, the Company issued $40.0 million aggregate principal amount of the Company’s 13.50% Convertible Second Lien Senior Secured Notes due 2019 (the “Convertible Second Lien Notes”) along with 10-year costless warrants to acquire 2.5 million shares of common stock. Holders of the Convertible Second Lien Notes had a second priority lien on all assets of the Company, and holders of such warrants had a right to appoint two members to our Board of Directors (the “Board”) as long as such warrants were outstanding.

 

The Convertible Second Lien Notes were scheduled to mature on August 30, 2019 or six months after the maturity of our current revolving credit facility but in no event later than March 30, 2020. The Convertible Second Lien Notes bore interest at the rate of 13.50% per annum, payable quarterly in arrears on January 15, April 15, July 15 and October 15 of each year. The Company also had the option under certain circumstances to pay all or any portion of interest in-kind on the then outstanding principal amount of the Convertible Second Lien Notes by increasing the principal amount of the outstanding Convertible Second Lien Notes or by issuing additional second lien notes.

 

Upon issuance of the Convertible Second Lien Notes in October 2016, in accordance with accounting standards related to convertible debt instruments that may be settled in cash upon conversion as well as warrants on the debt instrument, we recorded a debt discount of $11.0 million, thereby reducing the $40.0 million carrying value upon issuance to $29.0 million and recorded an equity component of $11.0 million. The debt discount was amortized using the effective interest rate method based upon an original term through August 30, 2019. The Convertible Second Lien Notes were redeemed in full on May 29, 2019 for $56.7 million using borrowings under the 2019 Senior Credit Facility. In connection with the redemption of the Convertible Second Lien Notes, we recorded a $1.6 million loss on early extinguishment of debt related to the remaining unamortized debt discount and debt issuance costs.

 

New Convertible Second Lien Notes 

 

On May 14, 2019, the Company and the Subsidiary entered into a purchase agreement with certain funds and accounts managed by Franklin Advisers, Inc., as investment manager (each such fund or account, together with its successors and assigns, a “New 2L Notes Purchaser”) pursuant to which the Company issued to the New 2L Notes Purchasers (the “New 2L Notes Offering”) $12.0 million aggregate principal amount of the Company’s 13.50% Convertible Second Lien Senior Secured Notes due 2021 (the “New 2L Notes”). The closing of the New 2L Notes Offering occurred on May 31, 2019. Proceeds from the sale of the New 2L Notes were primarily used to pay down outstanding borrowings under the 2019 Revolving Credit Facility. Holders of the New 2L Notes have a second priority lien on all assets of the Company.

 

The New 2L Notes, as set forth in the indenture governing such notes (as amended, the “New 2L Notes Indenture”), were initially scheduled to mature on May 31, 2021. In May 2020, the maturity date of the New 2L Notes was extended to May 31, 2022. The New 2L Notes bear interest at the rate of 13.50% per annum, payable quarterly in arrears on January 15, April 15, July 15 and October 15 of each year. The Company may elect to pay all or any portion of interest in-kind on the then outstanding principal amount of the New 2L Notes by increasing the principal amount of the outstanding New 2L Notes.

 

The New 2L Notes Indenture contains certain covenants pertaining to us and our Subsidiary, including delivery of financial reports; environmental matters; conduct of business; use of proceeds; operation and maintenance of properties; collateral and guarantee requirements; indebtedness; liens; dividends and distributions; limits on sales of assets and stock; business activities; transactions with affiliates; and changes of control. The New 2L Notes Indenture also contains a financial covenant which requires the maintenance of a ratio of Total Proved PV-10 attributable to the Company's and Subsidiary's Proved Reserves (as defined in the New 2L Notes Indenture) to Total Secured Debt (net of any Unrestricted Cash not to exceed $10.0 million) not to be less than 1.50 to 1.00.

 

The New 2L Notes are convertible into the Company’s common stock at the conversion rate, which is the sum of the outstanding principal amount of New 2L Notes to be converted, including any accrued and unpaid interest, divided by the conversion price, which shall initially be $21.33, subject to certain adjustments as described in the New 2L Notes Indenture. Upon conversion, the Company must deliver, at its option, either (1) a number of shares of its common stock determined as set forth in the New 2L Notes Indenture, (2) cash or (3) a combination of shares of its common stock and cash; however, the Company’s ability to redeem the New 2L Notes with cash is subject to the terms of the 2019 Senior Credit Agreement.

 

The New 2L Notes were issued and sold to the New 2L Notes Purchasers pursuant to an exemption from the registration requirements of the Securities Act of 1933, as amended, pursuant to Section 4(a)(2) thereunder. The Company has completed the registration with the U.S. Securities and Exchange Commission of the resale of the New 2L Notes and the shares of common stock issuable upon conversion of The New 2L Notes.

 

Upon issuance of the New 2L Notes on May 31, 2019, in accordance with accounting standards related to convertible debt instruments that may be settled in cash upon conversion, we recorded a debt discount of $1.4 million, thereby reducing the $12.0 million carrying value upon issuance to $10.6 million and recorded an equity component of $1.4 million. The equity component was valued using a binomial model. Prior to the maturity extension in May 2020, the debt discount was amortized using the effective interest rate method based upon an original term through May 31, 2021. Upon the maturity extension in May 2020, an additional $0.3 million of debt discount was recorded, and the debt discount began to be amortized using the effective interest rate method based upon the maturity date of May 31, 2022.

 

As of June 30, 2020, $1.1 million of debt discount and $0.2 million of debt issuance costs remained to be amortized on the New 2L Notes.

 

As of June 30, 2020, the Company was in compliance with all covenants within the New 2L Notes Indenture.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

 

NOTE 5—Equity

 

During the three and six months ended June 30, 2020, the Company had vestings of its share-based compensation units upon the retirement of certain employees which resulted in the issuance of approximately 130,000 common stock shares. The Company withheld shares for payment of $0.3 million in taxes due upon vesting resulting in approximately 38,000 shares held in treasury as of June 30, 2020. During the three and six months ended June 30, 2019, the Company did not have a material vesting of its share-based compensation units.

 

 

NOTE 6—Net Income (Loss) Per Common Share

 

Net income applicable to common stock was used as the numerator in computing basic and diluted net income (loss) per common share for the three and six months ended June 30, 2020 and 2019. The Company used the treasury stock method in determining the effects of potentially dilutive restricted stock. The following table sets forth information related to the computations of basic and diluted net income (loss) per common share:

 

		Three Months Ended June 30, 2020				Three Months Ended June 30, 2019				Six Months Ended June 30, 2020				Six Months Ended June 30, 2019
		(As Restated)								(As Restated)
		(Amounts in thousands, except per share data)
Basic net income (loss) per common share:
Net income (loss) applicable to common stock		$	(22,941	)		$	11,779			$	(19,905	)		$	12,227
Weighted average shares of common stock outstanding			12,540				12,211				12,536				12,181
Basic net income (loss) per common share		$	(1.83	)		$	0.96			$	(1.59	)		$	1.00
Diluted net income (loss) per common share:
Net income (loss) applicable to common stock		$	(22,941	)		$	11,779			$	(19,905	)		$	12,227
Interest, discount and amortization on New 2L Notes			-				107				-				107
Adjusted net income (loss) per common share		$	(22,941	)		$	11,886			$	(19,905	)		$	12,334
Weighted average shares of common stock outstanding			12,540				12,211				12,536				12,181
Common shares issuable upon conversion of the New 2L Notes			-				569				-				569
Common shares issuable upon conversion of warrants of unsecured claim holders			-				1,282				-				1,282
Common shares issuable on assumed conversion of restricted stock **			-				519				-				466
Diluted weighted average shares of common stock outstanding			12,540				14,581				12,536				14,498
Diluted net income (loss) per common share (1) (2) (3)		$	(1.83	)		$	0.82			$	(1.59	)		$	0.85
(1) Common shares issuable upon conversion of the New 2L Notes not included in the computation of diluted net loss per common share since their inclusion would have been anti-dilutive for the three and six months ended June 30, 2020.			650				-				650				-
(2) Common shares issuable upon conversion of the unsecured claims warrants not included in the computation of diluted net loss per common share since their inclusion would have been anti-dilutive for the three and six months ended June 30, 2020.			1,328				-				1,328				-
(3) Common shares issuable upon conversion of the restricted stock not included in the computation of diluted net loss per common share since their inclusion would have been anti-dilutive for the three and six months ended June 30, 2020. **			273				-				136				-

 

** Common shares issuable on assumed conversion of share-based compensation assumes a payout of the Company's performance share awards at 100% of the initial units granted (or a ratio of one unit to one common share). The range of common stock shares which may be earned ranges from zero to 250% of the initial performance units granted.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

 

NOTE 7—Income Taxes

 

We recorded no income tax expense or benefit for the three and six months ended June 30, 2020 or 2019. We maintained a valuation allowance at June 30, 2020, which resulted in no net deferred tax asset or liability appearing on our statement of financial position with the exception of a current tax receivable related to alternative minimum tax (“AMT”) credits. We recorded this valuation allowance after an evaluation of all available evidence (including commodity prices and our recent history of tax net operating losses in 2018 and prior years) led to a conclusion that based upon the more-likely-than-not standard of the accounting literature our deferred tax assets were unrecoverable. The valuation allowance was $74.2 million as of December 31, 2019, which resulted in a net non-current deferred tax asset of $0.4 million appearing on our statement of financial position at that time. The net $0.4 million deferred tax asset was reclassed to a current receivable as of June 30, 2020 and relates to AMT credits and accrued interest which are expected to be fully refunded in the third quarter of 2020. The valuation allowance has no impact on our net operating loss (“NOL”) position for tax purposes, and if we generate taxable income in future periods, we may be able to use our NOLs to offset taxable income at that time subject to any applicable tax limitations on the NOLs. Considering the Company’s taxable income forecasts, our assessment of the realization of our deferred tax assets has not changed, and we continue to maintain a full valuation allowance for our net deferred tax assets as of June 30, 2020.

 

As of June 30, 2020, we have no unrecognized tax benefits. There were no significant changes to our tax position since December 31, 2019.

 

 

NOTE 8—Commodity Derivative Activities

 

We use commodity and financial derivative contracts to manage fluctuations in commodity prices. We are currently not designating our derivative contracts for hedge accounting. All derivative gains and losses are from our oil and natural gas derivative contracts and have been recognized in “Other income (expense)” on our Consolidated Statements of Operations.

 

The following table summarizes gains and losses we recognized on our oil and natural gas derivatives for the three and six months ended June 30, 2020 and 2019:

 

		Three Months Ended June 30, 2020				Three Months Ended June 30, 2019				Six Months Ended June 30, 2020				Six Months Ended June 30, 2019
Oil and Natural Gas Derivatives (in thousands)
Gain on commodity derivatives not designated as hedges, settled		$	7,339			$	1,973			$	13,308			$	213
Gain (loss) on commodity derivatives not designated as hedges, not settled			(9,027	)			10,680				(5,858	)			11,432
Total gain (loss) on commodity derivatives not designated as hedges		$	(1,688	)		$	12,653			$	7,450			$	11,645

 

Commodity Derivative Activity

 

We enter into swap contracts, costless collars or other derivative agreements from time to time to manage commodity price risk for a portion of our production. Our policy is that all derivatives are approved by the Hedging Committee of our Board, and reviewed periodically by the Board.

 

Despite the measures taken by us to attempt to control price risk, we remain subject to price fluctuations for natural gas and crude oil sold in the spot market. Prices received for natural gas sold on the spot market are volatile due primarily to seasonality of demand and other factors beyond our control. Decreases in domestic crude oil and natural gas spot prices will have a material adverse effect on our financial position, results of operations and quantities of reserves recoverable on an economic basis. We routinely exercise our contractual right to net realized gains against realized losses when settling with our financial counter-parties. Neither our counter-parties nor we require any collateral upon entering into derivative contracts. We would have been at risk of losing $2.7 million and $0.4 million had RBC Capital Markets and Truist Bank, respectively, been unable to fulfill their obligations as of June 30, 2020. Included in net gain on cash settlements of natural gas and oil derivatives contracts for the three and six months ended June 30, 2020 was a $1.8 million gain from the cash settlement at the end of the quarter of our July 2020 natural gas derivative contracts.

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

As of June 30, 2020, the open positions on our outstanding commodity derivative contracts, all of which were with Truist Bank, RBC Capital Markets, ARM Energy and Citizens Commercial Banking were as follows:

 

Contract Type		Average Daily Volume			Total Volume		Weighted Average Fixed Price		Fair Value at June 30, 2020 (In thousands)
Oil swaps (Bbls)
2020		205			37,720		$ 57.95		$	691
2021 (through March 31, 2021)		200			18,000		$ 56.58			295
Total oil									$	986
Natural Gas swaps (MMBtu)
2020		45,000			6,824,000		$ 2.58		$	3,308
2021		48,000			17,589,000		$ 2.51			(1,420	)
2022 (through March 31, 2022)		50,000			4,500,000		$ 2.45			(1,109	)
Natural Gas collars (MMBtu)
2020		25,000			3,825,000		$2.40 - $2.62		$	1,382
2021 (through March 31, 2021)		27,000			2,430,000		$2.40 - $2.62			(672	)
Natural Gas basis swaps (MMBtu)
2020		50,000			9,200,000		$ 0.209		$	(127	)
2021		50,000			18,250,000		$ 0.209			(296	)
2022		50,000			18,250,000		$ 0.209			(515	)
2023		50,000			18,250,000		$ 0.209			(624	)
2024		50,000			18,300,000		$ 0.209			(989	)
Total natural gas									$	(1,062	)
Total oil and natural gas									$	(76	)

 

During the second quarter of 2020 we entered into the following contracts with Truist Bank, RBC Capital Markets and Citizens Commercial Banking:

 

Contract Type		Daily Volume			Weighted Average Fixed Price		Contract Start Date		Contract Termination
Natural gas swap (MMBtu)		10,000			$ 2.65		April 1, 2021		September 30, 2021
Natural gas swap (MMBtu)		10,000			$ 2.66		April 1, 2021		March 31, 2022

 

The following table summarizes the fair values of our derivative financial instruments that are recorded at fair value classified in each Level as of June 30, 2020 (in thousands). We measure the fair value of our commodity derivative contracts by applying the income approach. See Note 1—“Description of Business and Significant Accounting Policies” for our discussion regarding fair value, including inputs used and valuation techniques for determining fair values.

 

Description		Level 1				Level 2				Level 3				Total
Fair value of oil and natural gas derivatives - Current Assets		$	-			$	4,424			$	-			$	4,424
Fair value of oil and natural gas derivatives - Non-current Assets			-				-				-				-
Fair value of oil and natural gas derivatives - Current Liabilities			-				(352	)			-				(352	)
Fair value of oil and natural gas derivatives - Non-current Liabilities			-				(4,148	)			-				(4,148	)
Total		$	-			$	(76	)		$	-			$	(76	)

 

We enter into oil and natural gas derivative contracts under which we have netting arrangements with each counter-party. The following table discloses and reconciles the gross amounts to the amounts as presented on the Consolidated Balance Sheets as of June 30, 2020 and December 31, 2019:

 

		June 30, 2020												December 31, 2019
Fair Value of Oil and Natural Gas Derivatives		Gross				Amount				As				Gross				Amount				As
(in thousands)		Amount				Offset				Presented				Amount				Offset				Presented
Fair value of oil and natural gas derivatives - Current Assets		$	7,174			$	(2,750	)		$	4,424			$	9,401			$	(864	)		$	8,537
Fair value of oil and natural gas derivatives - Non-current Assets			446				(446	)			-				847				(816	)			31
Fair value of oil and natural gas derivatives - Current Liabilities			(3,102	)			2,750				(352	)			(864	)			864				-
Fair value of oil and natural gas derivatives - Non-current Liabilities			(4,594	)			446				(4,148	)			(3,602	)			816				(2,786	)
Total		$	(76	)		$	-			$	(76	)		$	5,782			$	-			$	5,782

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

 

NOTE 9—Commitments and Contingencies

 

We are party to various lawsuits from time to time arising in the normal course of business, including, but not limited to, royalty, contract, personal injury, and environmental claims. We have established reserves as appropriate for all such proceedings and intend to vigorously defend these actions. Management believes, based on currently available information, that adverse results or judgments from such actions, if any, would not have been material to our consolidated financial position, results of operations or liquidity for the three and six months ended June 30, 2020 and 2019.

 

 

NOTE 10—Leases

 

We determine if an arrangement is or contains a lease at inception. Leases with an initial term of 12 months or less are not recorded on our Consolidated Balance Sheets. We lease our corporate office building in Houston, Texas. We recognize lease expense for this lease on a straight-line basis over the lease term. This operating lease is included in furniture, fixtures and equipment and other capital assets, accrued liabilities and other non-current liabilities on our Consolidated Balance Sheets. The operating lease asset and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term. As this lease did not provide an implicit rate, we used a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, in determining the present value of future payments. The operating lease asset includes any lease payments made but excludes annual operating charges. Operating lease expense is recognized on a straight-line basis over the lease term and reported in general and administrative operating expense on our Consolidated Statements of Operations. We have also entered into leases for certain vehicles and other equipment which are immaterial to our financial statements and have therefore not been recorded on our Consolidated Balance Sheets.

 

The lease cost components for the three and six months ended June 30, 2020 and 2019 are classified as follows:

 

(in thousands)		Three Months Ended June 30, 2020				Three Months Ended June 30, 2019				Six Months Ended June 30, 2020				Six Months Ended June 30, 2019			Consolidated Statements of Operations Classification
Building lease cost		$	385			$	403			$	770			$	756		General and administrative expense
Variable lease cost (1)			6				48				25				95		General and administrative expense
		$	391			$	451			$	795			$	851

 

(1) Includes building operating expenses.

 

The following are additional details related to our lease portfolio as of June 30, 2020 and December 31, 2019:

 

(in thousands)		June 30, 2020				December 31, 2019			Consolidated Balance Sheets Classification
Lease asset, gross		$	2,922			$	2,922		Furniture, fixtures and equipment and other capital assets
Accumulated depreciation			(1,878	)			(1,252	)	Accumulated depletion, depreciation and amortization
Lease asset, net		$	1,044			$	1,670
Current lease liability		$	1,521			$	1,414		Accrued liabilities
Non-current lease liability			-				800		Other non-current liabilities
Total lease liabilities		$	1,521			$	2,214

 

 

GOODRICH PETROLEUM CORPORATION AND SUBSIDIARY

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

 

The following table presents operating lease liability maturities as of June 30, 2020:

 

(in thousands)		June 30, 2020
2020		$	770
2021			813
2022			-
2023			-
2024			-
Thereafter			-
Total lease payments		$	1,583
Less imputed interest			62
Present value of lease liabilities		$	1,521

 

As of June 30, 2020, our office building operating lease has a weighted-average remaining lease term of 0.8 years and a weighted-average discount rate of 8.0 percent. Cash paid for amounts included in the measurement of operating lease liabilities was $0.4 million for both the three and six months ended June 30, 2020 and 2019.

 

 

NOTE 11—COVID-19 Pandemic

 

The impact of the COVID-19 pandemic and related economic, business and market disruptions is both on-going and continuing to evolve, and its future effects are uncertain. The Company has seen impacts related to COVID-19 on oil price fluctuations due to market uncertainty.

 

Starting in May 2020, as COVID-19 appeared to decrease or stabilize in certain areas, certain local, regional and national authorities began to loosen restrictions in various locations. While this relaxation of restrictions has led to an increased demand for oil and natural gas through improved general economic conditions, there has also been a resurgence of COVID-19 cases in June and continuing into July that could result in the reinstatement of restrictions, which could lower demand for oil and natural gas.

 

Because we predominately produce natural gas and natural gas has not been impacted by the same market forces as crude oil, we have experienced less of an impact from COVID-19 than many of our peers. However, the scope and length of the economic downturn in the face of COVID-19 and the ultimate effect on the price of natural gas and oil cannot be determined, and we could be adversely affected in future periods. Management is actively monitoring the impact on the Company’s results of operations, financial position, and liquidity in fiscal year 2020.