UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

(Mark One)


ý	QUARTERL Y REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~September 30, 2019~~March 31, 2020


☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 001-37670

Lonestar Resources US Inc.

(Exact Name of Registrant as Specified in its Charter)



Delaware		81-0874035
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

111 Boland Street, Suite 301, Fort Worth, TX		76107
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code: (817) 921-1889

Securities Registered Pursuant to Section 12(b) of the Act:



Title of Each Class	Trading Symbol	Name of Exchange on Which Registered
Class A Voting Common Stock, par value $0.001 per share	LONE	NASDAQ Global Select Market

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý No ☐

Indicate by check mark whether the registrant has submitted electronically ~~and posted on its corporate Web site, if any,~~ every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T ~~(§ 232.405 of this chapter)~~ during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No ☐

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



Large accelerated filer	☐	Accelerated filer	ý☐
Non-accelerated filer	☐ý	Smaller reporting company	ý
		Emerging growth company	ý

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ý

As of ~~November 11, 2019,~~June 29, 2020, the registrant had ~~24,944,891~~25,369,191 shares of Class A voting common stock, par value $0.001 per share, outstanding.

EXPLANATORY NOTE

As previously disclosed in the Current Report on Form 8-K filed by Lonestar Resources US Inc. (the “Company”) on May 11, 2020, the Company expected that the filing of this Quarterly Report on Form 10-Q for the quarter ended March 31, 2020 (the “Report”), originally due on May 15, 2020, would be delayed due to disruptions caused by the COVID-19 coronavirus (“COVID-19”) pandemic. Specifically, the impact of COVID-19 on the Company and its employees, including disruptions in staffing, communications and access to personnel due to stay-at-home orders issued by the Governor of the state of Texas the week of March 30, 2020, resulted in delays, limited support and insufficient review. This, in turn, delayed the Company’s ability to complete its financial reporting process and prepare the Report.

The Company relied on Release No. 34-88465 issued by the Securities and Exchange Commission on March 25, 2020, pursuant to Section 36 of the Securities Exchange Act of 1934, as amended, to delay the filing of this Quarterly Report.

Table of Contents



		Page
PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements	1
	Unaudited Condensed Consolidated Balance Sheets at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019	1
	Unaudited Condensed Consolidated Statements of Operations for the Three ~~and Nine~~ Months Ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~	2
	Unaudited Condensed Consolidated Statements of Changes in Stockholders' Equity for the Three ~~and Nine~~ Months Ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~	3
	Unaudited Condensed Consolidated Statements of Cash Flows for the ~~Nine~~Three Months Ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~	4
	Notes to Unaudited Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2018
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3437
Item 4.	Controls and Procedures	3538
PART II.	OTHER INFORMATION	3639
Item 1.	Legal Proceedings	3639
Item 1A.	Risk Factors	3639
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3641
Item 3.	Default under Credit Facility	41
Item 6.	Exhibits	3742
Signatures		3843

iiiii

PART I—FINANCIAL INFORMATION

Item 1. Financial Statements

Lonestar Resources US Inc.

Unaudited Condensed Consolidated Balance Sheets

(In thousands, except par value and share data)


	September 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
Assets
Current assets
Cash and cash equivalents	$	3,441		$	5,355		$	1,142		$	3,137
Accounts receivable
Oil, natural gas liquid and natural gas sales	16,594			15,103			10,229			15,991
Joint interest owners and others, net	5,159			4,541			836			1,310
Related parties	5,213			301
Derivative financial instruments	15,798			15,841			74,425			5,095
Prepaid expenses and other	2,844			1,966			2,873			2,208
Total current assets	49,049			43,107			89,505			27,741
Property and equipment
Oil and gas properties, using the successful efforts method of accounting
Proved properties	1,009,545			960,711			1,083,692			1,050,168
Unproved properties	80,565			81,850			77,162			76,462
Other property and equipment	21,344			17,727			21,424			21,401
Less accumulated depreciation, depletion and amortization	(392,604		)	(369,529		)
Less accumulated depreciation, depletion, amortization and impairment							(688,692		)	(464,671		)
Property and equipment, net	718,850			690,759			493,586			683,360
Accounts receivable – related party							5,936			5,816
Derivative financial instruments	9,857			7,302			25,434			1,754
Other non-current assets	2,457			2,944			1,885			2,108
Total assets	$	780,213		$	744,112		$	616,346		$	720,779
Liabilities and Stockholders' Equity
Current liabilities
Accounts payable	$	34,363		$	18,260		$	33,284		$	33,355
Accounts payable – related parties	251			181
Accounts payable – related party							381			189
Oil, natural gas liquid and natural gas sales payable	15,286			13,022			15,257			14,811
Accrued liabilities	16,100			28,128			23,049			26,905
Derivative financial instruments	3,271			430			1,501			8,564
Current maturities of long-term debt							513,259			247,000
Total current liabilities	69,271			60,021			586,731			330,824
Long-term liabilities
Long-term debt	499,772			436,882			9,148			255,068
Asset retirement obligations	7,139			7,195			6,888			7,055
Deferred tax liabilities, net	5,387			12,370			—			931
Warrant liability	162			366			—			129
Warrant liability – related parties	299			689
Warrant liability – related party							1			235
Derivative financial instruments	4			21			1,896			1,898
Other non-current liabilities	3,360			4,021			1,346			3,752
Total long-term liabilities	516,123			461,544			19,279			269,068
Commitments and contingencies (Note 12)
Commitments and contingencies (Note 11)
Stockholders' Equity
Class A voting common stock, $0.001 par value, 100,000,000 shares authorized, 24,933,853 and 24,645,825 issued and outstanding, respectively	142,655			142,655
Series A-1 convertible participating preferred stock, $0.001 par value, 98,120 and 91,784 shares issued and outstanding, respectively	—			—
Class A voting common stock, $0.001 par value, 100,000,000 shares authorized, 25,254,029 and 24,945,594 shares issued and outstanding, respectively							142,655			142,655
Series A-1 convertible participating preferred stock, $0.001 par value, 102,585 and 100,328 shares issued and outstanding, respectively							—			—
Additional paid-in capital	175,709			174,379			175,978			175,738
Accumulated deficit	(123,545		)	(94,487		)	(308,297		)	(197,506		)
Total stockholders' equity	194,819			222,547			10,336			120,887
Total liabilities and stockholders' equity	$	780,213		$	744,112		$	616,346		$	720,779

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

Lonestar Resources US Inc.

Unaudited Condensed Consolidated Statements of Operations

(In thousands, except per share data)


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
Revenues
Oil sales	$	42,187		$	47,846		$	120,496		$	120,705		$	29,990		$	33,584
Natural gas liquid sales	3,439			6,795			10,381			12,939			2,599			3,393
Natural gas sales	7,519			4,096			15,224			9,637			4,420			3,764
Total revenues	53,145			58,737			146,101			143,281			37,009			40,741
Expenses
Lease operating and gas gathering	10,055			6,687			26,695			17,761			9,788			7,710
Production and ad valorem taxes	3,017			3,218			8,126			8,145			2,369			2,291
Depreciation, depletion and amortization	24,635			23,775			64,120			59,937			24,354			17,970
Loss on sale of oil and gas properties	483			—			33,530			1,568			—			32,894
Impairment of oil and gas properties	—			12,169			—			12,169			199,908			—
General and administrative	4,124			4,661			12,345			13,385			2,881			4,379
Acquisition costs and other	(2		)	315			(4		)	302
Other													(223		)	(2		)
Total expenses	42,312			50,825			144,812			113,267			239,077			65,242
Income from operations	10,833			7,912			1,289			30,014
Other expense
Loss from operations													(202,068		)	(24,501		)
Other income (expense)
Interest expense	(11,295		)	(10,215		)	(32,730		)	(28,771		)	(11,610		)	(10,656		)
Change in fair value of warrants	(100		)	509			594			(2,105		)	363			(102		)
Gain (loss) on derivative financial instruments	21,546			(18,198		)	(5,177		)	(54,852		)	101,169			(36,238		)
Loss on extinguishment of debt	—			—			—			(8,619		)
Total other expense	10,151			(27,904		)	(37,313		)	(94,347		)
Income (loss) before income taxes	20,984			(19,992		)	(36,024		)	(64,333		)
Income tax (expense) benefit	(4,767		)	282			6,966			6,493
Net income (loss)	16,217			(19,710		)	(29,058		)	(57,840		)
Total other income (expense)													89,922			(46,996		)
Loss before income taxes													(112,146		)	(71,497		)
Income tax benefit													1,355			12,933
Net Loss													(110,791		)	(58,564		)
Preferred stock dividends	(2,159		)	(1,975		)	(6,336		)	(5,796		)	(2,257		)	(2,065		)
Net income (loss) attributable to common stockholders	$	14,058		$	(21,685	)	$	(35,394	)	$	(63,636	)
Net loss attributable to common stockholders													$	(113,048	)	$	(60,629	)

Net income (loss) per common share
Net loss per common share
Basic	$	0.34		$	(0.88	)	$	(1.42	)	$	(2.59	)	$	(4.52	)	$	(2.45	)
Diluted	$	0.33		$	(0.88	)	$	(1.42	)	$	(2.59	)	$	(4.52	)	$	(2.45	)

Weighted average common shares outstanding
Basic	24,933,853			24,599,744			24,852,994			24,598,816			25,003,977			24,698,372
Diluted	25,331,810			24,599,744			24,852,994			24,598,816			25,003,977			24,698,372

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

Lonestar Resources US Inc.

Unaudited Condensed Consolidated Statements of Changes in Stockholders’ Equity

(In thousands, except share data)


	Class A Voting Common Stock					Series A-1 Preferred Stock				Additional Paid-in Capital				Accumulated Deficit					Total Stockholders' Equity			Class A Voting Common Stock							Series A-1 Preferred Stock				Additional Paid-in Capital			Accumulated Deficit				Total Stockholders' Equity
	Shares		Amount			Shares	Amount						Shares									Amount				Shares		Amount
Balance at December 31, 2018	24,645,825		$	142,655		91,784	$	—				$	174,379					$	(94,487	)			$	222,547
Balance at December 31, 2019																						24,945,594			$	142,655			100,328	$	—		$	175,738		$	(197,506	)		$	120,887
Payment-in-kind dividends	—		—			2,065	—			—				—					—			—			—				2,257	—			—			—				—
Stock-based compensation	127,818		—			—	—			627				—					627			308,435			—				—	—			240			—				240
Net loss	—		—			—	—			—				(58,564		)			(58,564		)	—			—				—	—			—			(110,791		)		(110,791		)
Balance at March 31, 2019	24,773,643	—	142,655		—	93,849	—		—	175,006		—		(153,051		)	—		164,610
Payment-in-kind dividends	—		—			2,112	—			—				—					—
Stock-based compensation	160,210		—			—	—			703				—					703
Net income	—		—			—	—			—				13,289					13,289
Balance at June 30, 2019	24,933,853		142,655			95,961	—			175,709				(139,762		)			178,602
Payment-in-kind dividends	—		—			2,159	—			—				—					—
Net income	—		—			—	—			—				16,217					16,217
Balance at September 30, 2019	24,933,853		$	142,655		98,120	$	—		$	175,709			$	(123,545	)			$	194,819
Balance at March 31, 2020																						25,254,029		—	142,655		—		102,585	—		—	175,978		—	(308,297		)	—	10,336


	Class A Voting Common Stock			Series A-1 Preferred Stock			Additional Paid-in Capital				Accumulated Deficit				Total Stockholders' Equity			Class A Voting Common Stock				Series A-1 Preferred Stock			Additional Paid-in Capital		Accumulated Deficit			Total Stockholders' Equity
	Shares	Amount		Shares	Amount					Shares					Total Stockholders' Equity			Amount			Shares	Amount			Additional Paid-in Capital		Accumulated Deficit			Total Stockholders' Equity
Balance at December 31, 2017	24,506,647	$	142,655	83,968	$	—	Additional Paid-in Capital		$	174,871	Accumulated Deficit			$	(113,836	)		$	203,690
Balance at December 31, 2018																		24,645,825		$	142,655	91,784	$	—	$	174,379	$	(94,487	)	$	222,547
Payment-in-kind dividends	—	—		1,889	—		—				—				—			—		—		2,065	—		—		—			—
Issued pursuant to stock-based compensation plan	127,666	—		—	—		(610		)		—				(610		)
Stock-based compensation	—	—		—	—		216				—				216			127,818		—		—	—		627		—			627
Net loss	—	—		—	—		—				(16,537		)		(16,537		)	—		—		—	—		—		(58,564		)	(58,564		)
Balance at March 31, 2018	24,634,313	142,655		85,857	—		174,477				(130,373		)		186,759
Payment-in-kind dividends	—	—		1,932	—		—				—				—
Issued pursuant to stock-based compensation plan	—	—		—	—		9				—				9
Stock-based compensation	2,814	—		—	—		(17		)		—				(17		)
Net loss	—	—		—	—		—				(21,593		)		(21,593		)
Balance at June 30, 2018	24,637,127	142,655		87,789	—		174,469				(151,966		)		165,158
Payment-in-kind dividends	—	—		1,975	—		—				—				—
Retirement of Class B Common Stock	—	—		—	—		(10		)		—				(10		)
Net loss	—	—		—	—		—				(19,710		)		(19,710		)
Balance at September 30, 2018	24,637,127	$	142,655	89,764	$	—	$	174,459			$	(171,676	)		$	145,438
Balance at March 31, 2019																		24,773,643		142,655		93,849	—		175,006		(153,051		)	164,610

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

Lonestar Resources US Inc.

Unaudited Condensed Consolidated Statements of Cash Flows

(In thousands)


	Nine Months Ended September 30,							Three Months Ended March 31,
	2019				2018			2020			2019
Cash flows from operating activities
Net loss	$	(29,058	)		$	(57,840	)	$	(110,791	)	$	(58,564	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Accretion of asset retirement obligations								86			79
Depreciation, depletion and amortization	64,120				59,937			24,268			17,891
Stock-based compensation	1,294				3,637			(2,022		)	533
Stock-based payments	—			��	(601		)
Deferred taxes	(6,983		)		(7,145		)	(1,376		)	(12,922		)
Loss on derivative financial instruments	5,177				54,852
(Gain) loss on derivative financial instruments								(101,169		)	36,238
Settlements of derivative financial instruments	(3,858		)		(16,323		)	1,096			1,309
Impairment of oil and natural gas properties	—				12,169			199,908			—
Gain on disposal of property and equipment	(17		)		—			83			(17		)
Loss on abandoned property and equipment	—				171
Loss on sale of oil and gas properties	33,530				—			—			32,894
Non-cash interest expense	1,822				4,556			768			699
Change in fair value of warrants	(594		)		2,105			(363		)	102
Changes in operating assets and liabilities:
Accounts receivable	(8,330		)		(4,596		)	6,117			(2,016		)
Prepaid expenses and other assets	(1,102		)		(1,835		)	(374		)	304
Accounts payable and accrued expenses	(3,128		)		6,733			(2,396		)	(6,704		)
Net cash provided by operating activities	52,873				55,820			13,835			9,826

Cash flows from investing activities
Acquisition of oil and gas properties	(5,239		)		(4,762		)	(816		)	(2,352		)
Development of oil and gas properties	(119,273		)		(122,691		)	(34,753		)	(29,137		)
Proceeds from sale of oil and gas properties	11,470				—			317			12,107
Purchases of other property and equipment	(3,527		)		(1,631		)	(524		)	(2,916		)
Net cash used in investing activities	(116,569		)		(129,084		)	(35,776		)	(22,298		)

Cash flows from financing activities
Proceeds from borrowings	114,000				348,744			28,000			30,000
Payments on borrowings	(52,218		)		(273,466		)	(8,054		)	(19,116		)
Repurchase and retire Class B Common Stock	—				(10		)
Net cash provided by financing activities	61,782				75,268			19,946			10,884
Net (decrease) increase in cash and cash equivalents	(1,914		)		2,004
Net decrease in cash and cash equivalents								(1,995		)	(1,588		)
Cash and cash equivalents, beginning of the period	5,355				2,538			3,137			5,355
Cash and cash equivalents, end of the period	$	3,441			$	4,542		$	1,142		$	3,767

Supplemental information:
Cash paid for taxes	$	—			$	1,147
Cash paid for interest	28,125				22,324			$	3,957		$	16,743
Non-cash investing and financing activities:
Change in asset retirement obligation	$	(292	)		$	222		$	(253	)	$	(522	)
Change in liabilities for capital expenditures	9,098				16,988			(1,040		)	730

See accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

Lonestar Resources US Inc.

Notes to Unaudited Condensed Consolidated Financial Statements

Note 1. Basis of Presentation

Organization and Nature of Operations

Lonestar Resources US Inc. (“Lonestar” or the "Company") is a Delaware corporation whose common stock is listed and traded on the Nasdaq Global Select Market under the symbol “LONE”. Lonestar is an independent oil and natural gas company focused on the exploration, development and production of unconventional oil, natural gas liquids and natural gas in the Eagle Ford Shale play in South Texas.

Interim Financial Statements

The accompanying unaudited condensed consolidated financial statements of Lonestar Resources US Inc., and its subsidiaries have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) and do not include all of the information and footnotes required by accounting principles generally accepted in the United States for complete financial statements. These financial statements and the notes thereto should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, ~~2018~~2019 filed on ~~March~~April 13, ~~2019~~2020 (the “Form 10-K”). Unless indicated otherwise or the context requires, the terms “we,” “our,” “us,” “Company” or “Lonestar,” refer to Lonestar Resources US Inc. and its subsidiaries.

The results of operations for the interim periods shown in this report are not necessarily indicative of results to be expected for the year. In management’s opinion, the accompanying unaudited condensed consolidated financial statements include all adjustments of a normal recurring nature necessary for a fair statement of our consolidated financial position as of ~~September 30, 2019~~March 31, 2020 and our consolidated results of operations for the three ~~and nine~~ months ended ~~September~~March 31, 2020 and 2019.

Risks and Uncertainties

The COVID-19 pandemic has caused a rapid and precipitous drop in demand for oil, which in turn has caused oil prices to plummet since the first week of March 2020, negatively affecting the Company’s cash flow, liquidity and financial position. These events have worsened an already deteriorated oil market that resulted from the early-March 2020 failure by the group of oil producing nations known as OPEC+ to reach an agreement over proposed oil production cuts. Moreover, the uncertainty about the duration of the COVID-19 pandemic has caused storage constraints in the United States resulting from over-supply of produced oil, which has significantly decreased our realized oil prices in the second quarter of 2020 and potentially beyond. Oil prices are expected to continue to be volatile as a result of these events and the ongoing COVID-19 outbreak, and as changes in oil inventories, oil demand and economic performance are reported. The Company cannot predict when oil prices will improve and stabilize.

The current pandemic and uncertainty about its length and depth in future periods has caused the realized oil prices the Company has received since February 2020 to be significantly reduced, adversely affecting its operating cash flow and liquidity. Although the Company has reduced its 2020 capital expenditures budget, the lower levels of cash flow may require it to shut-in production that has become uneconomic in addition to shut-ins of production that the Company performed during the second quarter of 2020 (see below).

The COVID-19 pandemic is rapidly evolving, and the ultimate impact of this pandemic is highly uncertain and subject to change. The extent of the impact of the COVID-19 pandemic on the Company's operational and financial performance will depend on future developments, including the duration and spread of the pandemic, its severity, the actions to contain the disease or mitigate its impact, related restrictions on travel, and the duration, timing and severity of the impact on domestic and global oil demand.

In response to these developments, the Company has implemented the following operational and financial measures:

Reduced budgeted 2020 capital spending from $80-$85 million to $55-$65 million, or 27% at midpoint;

Deferred its 2020 drilling program;

Implemented cost-reduction measures including negotiations reducing rates for water disposal, chemicals, rentals, and workovers;

Shut in or stored approximately 4,700 BOE per day of production during late-April and all of May 2020, primarily at the Company's Central Eagle Ford Area. These shut-in wells back online during the first week of June.

Entered into additional commodities derivatives in March 2020 to hedge an additional 2,000 Bbls of oil per day at an average swap price of $41.00 per Bbl and 27,500 Mcf of natural gas per day at an average price of $2.36 per Mcf in 2021. The Company's current oil hedge position covers 7,498 Bbls per day for the second quarter of 2020, 7,565 Bbls per day for the second half of 2020, and 7,000 Bbls per day for 2021. The Company's current natural gas hedge position covers 20,000 Mcf per day for the remaining three quarters of 2020, and 27,500 Mcf per day for 2021.

Recent Developments

The Company's present level of indebtedness and the current commodity price environment present challenges to its ability to comply with the covenants in its Credit Facility (see Note 7. Long-Term Debt) over the next twelve months and therefore substantial doubt exists that the Company will be able to continue as a going concern. As of March 31, 2020, the Company had total indebtedness of $522.4 million, including $250.0 million of Senior Notes due 2023 (the “11.25% Senior Notes"), $267.0 million under the Company's Credit Facility and $8.9 million under the Company's building loan. As of July 2, 2020, the Company's Credit Facility is drawn to $285.0 million and is subject to a $60.4 million borrowing-base deficiency due to the terms of the Forbearance Agreement (see below).

The Company did not satisfy the consolidated current ratio covenant under the Credit Facility as of the March 31, 2020 measurement date and did not make the July 1, 2020 interest payment under the 11.25% Senior Notes. Such failures represent events of default under our revolving credit facility, and the missed interest payment will represent an event of default under the 11.25% Senior Notes if not cured within 30 days. The Company received a forbearance from the lenders under the Credit Facility until July 31, 2020 for the defaults in the consolidated current ratio covenant as of the March 31, 2020 measurement date and the missed interest payment pursuant to the Forbearance Agreement. Despite the forbearance, the defaults under the Credit Facility are continuing, and will continue, absent a waiver or amendment from the Credit Facility lenders.

Forbearance Agreement

On July 2, 2020, the Company entered into a Forbearance Agreement, Fourteenth Amendment, and Borrowing Base Agreement with Citibank, N.A., as administrative agent and the lenders party thereto (the “Forbearance Agreement”) with respect to the Credit Facility. Pursuant to the Forbearance Agreement, among other things, (i) the lenders under the Credit Facility agreed to refrain from exercising their rights and remedies under the Credit Facility and related loan documents with respect to certain defaults until July 31, 2020, (ii) the borrowing base was redetermined to $225 million from $286 million, (iii) all proceeds of dispositions and terminations or liquidations of swap agreements shall be used to repay the Credit Facility and shall automatically reduce the borrowing base by the amount of the repayment and (iv) certain exceptions to the covenant restriction on investments shall no longer be available.

The rights of the Credit Facility lenders to exercise rights and remedies resulted from the Company's failure to comply with the current ratio with respect to the quarter ended March 31, 2020 and the defaults expected with respect to the quarter ending June 30, 2020 under the current ratio and the leverage ratio covenants, and the default with respect to the failure to make the interest payment due on July 1, 2020, under the 11.25% Senior Notes.

The Forbearance Agreement can be terminated by the lenders upon (i) the occurrence of any default or event of default under the Credit Facility other than those disclosed above, (ii) the failure of the Company to comply with any of the terms and requirements of the Forbearance Agreement, (iii) the breach of any representation or warranty, (iv) the exercise of any rights by other debt holders relating to foreclosure or acceleration (including acceleration of the 11.25% Senior Notes in the event of default) and (v) the commencement of any bankruptcy proceeding with respect to any loan party. Additionally, the Forbearance Agreement can be terminated if the Company fails to deliver a detailed restructuring proposal to the lenders by July 16, 2020. If the Forbearance Agreement terminates and any then-current and ongoing events of default have not been waived or cured, the lenders will be able to accelerate the loans and pursue their rights and remedies.

Borrowing Base Redetermination

As of March 31, 2020, the borrowing base and lender commitments for the Credit Facility were $290 million. However, subsequent to the end of the first quarter of 2020, the borrowing base was lowered to $286 million on June 11, 2020 as part of the Thirteenth Amendment (see Note 7. Long-Term Debt), and the borrowing base was later redetermined to $225 million from $286 million pursuant to the Forbearance Agreement on July 2, 2020, which created a deficiency between the outstanding amount borrowed under the Company's revolving credit facility and the borrowing base. The outstanding balance under the Credit Facility was $285 million as of July 2, 2020 which represents a borrowing deficiency of $60.4 million. The Company is obligated to pay the deficiency within 60 days after July 2, 2020 due to the Credit Facility being in a state of default at the time of the deficiency, as noted below.

Going Concern

The Company has concluded that these circumstances create substantial doubt regarding its ability to continue as a going concern. However, these consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty and instead have been prepared on a going concern basis, which contemplates the realization of assets and the settlement of liabilities and commitments in the normal course of business.

The Company does not anticipate maintaining compliance with the consolidated current ratio covenant under its Credit Facility over the next twelve months, and is evaluating the available financial alternatives, including obtaining acceptable alternative financing as well as seeking additional waivers, forbearances or amendments to the covenants or other provisions of the Credit Facility to address any existing or future defaults and have engaged financial and legal advisors to assist the Company. If the Company is unable to reach an agreement with its lenders or find acceptable alternative financing, the lenders of the Credit Facility may choose to accelerate repayment, in addition to the $60.4 million due from the current borrowing base deficiency noted above, which in turn may result in an event of default and an acceleration of the 11.25% Senior Notes, which have a $14.1 million interest payment that was due and unpaid on July 1, 2020 (see below). If the Company's lenders or its noteholders accelerate the payment of amounts outstanding under our Credit Facility or the 11.25% Senior Notes, respectively, the Company does not currently have sufficient liquidity to repay such indebtedness and would need additional sources of capital to do so.

The Company cannot provide any assurances that it will be successful in any restructuring of existing debt obligations or obtaining capital sufficient to fund the refinancing of its outstanding indebtedness or to provide sufficient liquidity to meet its operating needs. If the Company is unsuccessful in its efforts to restructure and obtain new financing, it may be necessary for it to seek protection from creditors under Chapter 11 of the U.S. Bankruptcy Code (“Chapter 11”), or an involuntary petition for bankruptcy may be filed against it.

Impairment of Long-Lived Assets

The carrying value of long-lived assets and certain identifiable intangibles are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. When it is determined that the estimated future net cash flows of an asset will not be sufficient to recover its carrying amount, an impairment loss must be recorded to reduce the carrying amount to its estimated fair value. Judgments and assumptions are inherent in management’s estimate of undiscounted future cash flows and an asset’s fair value. These judgments and assumptions include such matters as the estimation of oil and gas reserve quantities, risks associated with the different categories of oil and gas reserves, the timing of development and production, expected future commodity prices, capital expenditures, production costs, and appropriate discount rates.

The Company evaluates impairment of proved and unproved oil and gas properties on a region basis. On this basis, certain regions may be impaired because they are not expected to recover their entire carrying value from future net cash flows. As a result of this evaluation, the Company recorded impairment oil and gas properties of $199.9 million for the three months ended March 31, 2020, of which $199.0 million was proved and $0.9 million was unproved. The impairment was the result of removing development of PUD and probable reserves from future net cash flows as the Company cannot assure that they will be developed going forward in light of continued depressed commodity prices and uncertainty regarding the Company's liquidity situation. If pricing remains depressed, it is reasonably likely that the Company may have to record impairment of its oil and gas properties in the future.

CAREs Act

On March 27, 2020, Congress enacted the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) to provide certain taxpayer relief as a result of the COVID-19 pandemic. The CARES Act included several favorable provisions that impacted income taxes, primarily the modified rules on the deductibility of business interest expense for 2019 and ~~2018.~~2020, a five-year carryback period for net operating losses generated after 2017 and before 2021, and the acceleration of refundable alternative minimum tax credits. The CARES Act did not materially impact the Company's effective tax rate for the three months ended March 31, 2020.

The Company has applied for, and has received, funds under the Paycheck Protection Program after the period end in the amount of $2.2 million. The application for these funds requires the Company to, in good faith, certify that the current economic uncertainty made the loan request necessary to support the ongoing operations of the Company. This certification further requires the Company to take into account our current business activity and our ability to access other sources of liquidity sufficient to support ongoing operations in a manner that is not significantly detrimental to the business. The receipt of these funds, and the forgiveness of the loan attendant to these funds, is dependent on the Company having initially qualified for the loan and qualifying for the forgiveness of such loan based on our future adherence to the forgiveness criteria.

Net ~~Income (Loss)~~Loss per Common Share

The two-class method is utilized to compute earnings per common share as our Class A Participating Preferred Stock (the "Preferred Stock") is considered a participating security. Under the two-class method, losses are allocated only to those securities that have a contractual obligation to share in the losses of the Company. The Preferred Stock is not obligated to absorb Company losses and accordingly is not allocated losses. Net income attributable to common stockholders is allocated between common stock and participating securities based on the weighted average number of common shares and participating securities outstanding for the period.

Basic earnings per share is computed by dividing the allocated net income (loss) attributable to common stockholders by the weighted-average number of shares of common stock outstanding for the period.

Diluted earnings per share is computed similarly except that the denominator is increased to include dilutive potential common shares. Potential common shares consist of warrants, equity compensation awards and Preferred Stock. In certain circumstances adjustment to the numerator is also required for changes in income or loss resulting from the potential common shares. Basic weighted average common shares exclude shares of non-vested restricted stock. As these restricted shares vest, they will be included in the shares outstanding used to calculate basic earnings per share.

~~The following is a reconciliation of~~For the periods presented, there were no differences between the basic and diluted ~~earnings per share:~~

In thousands, except shares and per-share data Three Months Ended September 30, Nine Months Ended September 30,
2019 2018 2019 2018
Numerator - Basic
Net income (loss) attributable to common stockholders $ 14,058
$ (21,685 ) $ (35,394 ) $ (63,636 )
Less: allocation to participating securities (5,494 ) —
—
—
Net income (loss) allocated to common stockholders - basic $ 8,564
$ (21,685 ) $ (35,394 ) $ (63,636 )

Numerator - Diluted
Net income (loss) allocated to common stockholders - basic $ 8,564

$ (21,685 )
$ (35,394 )
$ (63,636 )
Restricted stock unit compensation gain, net of tax (80 ) —
—
—
Net income (loss) allocated to common stockholders - diluted $ 8,484

$ (21,685 )
$ (35,394 )
$ (63,636 )

Denominator
Weighted average number of common shares - basic 24,933,853
24,599,744
24,852,994
24,598,816
Restricted stock units converted under the treasury stock method 397,957
—
—
—
Weighted average number of common shares - diluted 25,331,810

24,599,744

24,852,994

24,598,816

Earnings per share
Basic $ 0.34

$ (0.88 )
$ (1.42 )
$ (2.59 )
Diluted $ 0.33
$ (0.88 ) $ (1.42 ) $ (2.59 )

weighted average common shares. The following ~~weighted average~~ securities could potentially dilute earnings per share ~~for~~in the ~~periods indicated,~~future, but were excluded from the computation of diluted net ~~income (loss)~~loss per share, as their effect would have been antidilutive:


	Three Months Ended September 30,		Nine Months Ended September 30,		Three Months Ended March 31,
	2019	2018	2019	2018	2020	2019
Preferred stock	15,997,411	14,635,078	15,649,269	14,316,581	16,725,467	15,301,157
Warrants	760,000	760,000	760,000	760,000	760,000	760,000
Stock appreciation rights	1,010,000	1,017,500	1,010,000	901,108	1,010,000	1,010,000
Restricted stock units	—	1,037,209	1,457,701	890,744	1,925,366	834,397

Recent Accounting Pronouncements

~~Leases.~~Reference Rate Reform. In ~~February 2016, the FASB issued Accounting Standards Update ("ASU") 2016-02,~~ ~~Leases~~ ("ASU 2016-02"). The standard requires lessees to recognize a right of use asset ("ROU asset") and lease liability on the balance sheet for the rights and obligations created by leases. ASU 2016-02 also requires disclosures designed to give financial statement users information on the amount, timing, and uncertainty of cash flows arising from leases. In July 2018,March 2020, the FASB issued ASU ~~2018-11,~~ 2020-04,~~Leases~~ Reference Rate Reform (Topic ~~842): Targeted Improvements~~ 848)(" (“ASU ~~2018-11"~~2020-04”)~~, which~~. ASU 2020-04 provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions to ease financial reporting burdens related to the expected market transition from the London Interbank Offered Rate (“LIBOR”) or another reference rate to alternative reference rates. The amendments in this ASU are effective beginning on March 12, 2020, and an ~~alternative transition method by allowing entities~~entity may elect to ~~initially~~ apply the ~~new leases standard at~~amendments prospectively through December 31, 2022. The Company is currently evaluating the ~~adoption date, January 1, 2019, and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. Comparative periods presented in the~~impact this guidance may have on its consolidated financial statements ~~continue to be in accordance with ASC Topic 840,~~ ~~Leases~~.and related footnote disclosures.

Income Taxes.In December 2019, the ~~normal course~~FASB issued ASU 2019-12, Income Taxes (Topic 740) – Simplifying the Accounting for Income Taxes (“ASU 2019-12”). The objective of ~~business,~~ASU 2019-12 is to simplify the ~~Company enters into lease agreements~~accounting for income taxes by removing certain exceptions to ~~support its exploration~~the general principles in Topic 740 and ~~development operations~~to provide more consistent application to improve the comparability of financial statements. The amendments in this ASU are effective for fiscal years beginning after December 15, 2020, and ~~lease assets, such as drilling rigs, field services, well equipment, office space and other assets.~~early adoption is permitted. The Company ~~adopted~~is currently evaluating the ~~new standard~~impact this guidance may have on ~~the effective date of January 1, 2019, using a modified retrospective approach as permitted under ASU 2018-11.~~

~~The new standard provides a number of optional practical expedients in transition. The Company:~~

~~• elected the package of 'practical expedients', which permits the Company not to reassess, under the new standard,~~ its ~~prior conclusions about lease identification, lease classification~~consolidated financial statements and ~~initial direct costs;~~

~~• elected the practical expedient pertaining to land easements and plan to account for existing land easements under the Company's current accounting policy;~~

• elected the short-term lease recognition exemption for all leases that qualify and, as such, no ROU asset or lease liability has been recorded on the balance sheet and no transition adjustment has been required for short-term leases; and

~~• elected the practical expedient to not separate lease and non-lease components for all of the Company's leases.~~

~~The Company did not elect the hindsight practical expedient in determining the lease term and assessing impairment of ROU assets when transitioning to ASU 2016-02.~~

~~Upon adoption, the Company recognized additional operating lease liabilities of approximately $0.3 million with corresponding ROU assets. See Note 4.~~ related footnote disclosures.~~Leases~~ ~~for more information.~~

Note 2. Acquisitions and Divestitures

Pirate Divestiture

In March ~~22,~~ 2019, Lonestar completed the divestiture of its Pirate assets in Wilson County for ~~$12.3~~an adjusted cash purchase price of $11.5 million, ~~before~~after closing adjustments, to a private third-party. The assets were comprised of 3,400 net undeveloped acres, six producing wells, held seven proved undeveloped locations as of the closing date, and were producing approximately 200 BOE/d. The Company recognized a loss of $33.5 million during the first quarter of 2019 in conjunction with the sale of the assets.

~~Sooner Acquisition~~

On November 15, 2018, Lonestar completed the acquisition of oil and gas properties in the Sugarkane Field in DeWitt County, Texas, for $38.7 million, before closing adjustments, from Sabine Oil & Gas Corporation and Alerion Gas AXA, LLC (the “Sooner Acquisition”). The acquisition was financed with funds available from our Credit Facility, as well as cash from operations. The Sooner Acquisition was accounted for as an asset acquisition applying the guidance of ASU 2017-01. As such, the properties were recorded based on the fair value of the total consideration transferred on the acquisition date, and all of the value of the transaction was allocated to proved oil and gas properties. Transaction costs of $0.3 million were capitalized as a component of the cost of the assets acquired.

~~Corporate Headquarters~~

On August 2, 2017, the Company closed on the purchase of an office building in Fort Worth, Texas, with an acquisition price approximating $10.0 million, to which the Company relocated its corporate operations in February 2018. In light of the relocation, the Company recorded an impairment charge of $1.6 million in Acquisition Costs and Other expense on the Unaudited Condensed Consolidated Statement of Operations during the first quarter of 2018, primarily reflecting the remaining future minimum rentals of the lease for the Company’s prior corporate office from the date of relocation to the end of the remaining lease term.

~~In February 2019, the Company acquired an adjacent property for $2.0 million. The property was acquired for future expansion.~~

Note 3. Derivative Instruments and Hedging Activities

Commodity ~~Price Risk Activities~~Derivative Instruments

Lonestar enters into certain commodity derivative instruments to mitigate commodity price risk associated with a portion of its future oil, NGL and natural gas production and related cash flows. The oil, NGL and natural gas revenues and cash flows are affected by changes in commodity product prices, which are volatile and cannot be accurately predicted. The objective for entering into these commodity derivatives is to protect the operating revenues and cash flows related to a portion of the future oil, NGL and natural gas sales from the risk of significant declines in commodity prices, which helps ensure the Company’s ability to fund the capital budget.

Inherent in Lonestar's fixed price contracts are certain business risks, including market risk and credit risk. Market risk is the risk that the price of oil and natural gas will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from non-performance by the Company’s counterparty to a contract. The Company does not currently require cash collateral from any of its counterparties nor does its counterparties require cash collateral from the Company. As of ~~September 30, 2019,~~March 31, 2020, the Company had no open physical delivery ~~obligations.The~~obligations.

The following table summarizes Lonestar's commodity derivative contracts as of ~~September 30, 2019:~~March 31, 2020:


	Contract			Volumes	Weighted		Contract			Volumes	Weighted
Commodity	Type	Period	Range ⁽¹⁾	(Bbls/Mcf per day)	Average Price		Type	Period	Range ⁽¹⁾	(Bbls/Mcf per day)	Average Price
Oil - WTI	Swaps	Oct - Dec 2019	$48.04 - $69.57	7,212	$	54.54	Swaps	Apr - June 2020	$48.90 - $65.56	7,498	$	56.50
Oil - Argus WTI ⁽²⁾	Basis Swaps	Oct - Dec 2019	5.00 - 5.55	6,000	5.05
Oil - WTI	Swaps	Jan - Dec 2020	48.90 - 65.56	7,480	56.95		Swaps	July - Dec 2020	51.60 - 65.56	7,565	57.38
Oil - WTI	Swaps	Jan - Dec 2021	51.05 - 56.50	3,000	54.68		Swaps	Jan - Dec 2021	40.95 - 56.50	7,000	50.40
Natural Gas - Henry Hub	Swaps	Oct - Dec 2019	2.76 - 2.98	15,000	2.87		Swaps	Apr - Dec 2020	2.38 - 2.80	20,000	2.55
Natural Gas - Henry Hub	Swaps	Jan - Dec 2020	2.59 - 2.59	15,000	2.59		Swaps	Jan - Dec 2021	2.32 - 2.39	27,500	2.36

(1) Ranges presented for fixed-price swaps and basis swaps represent the lowest and highest fixed prices of all open contracts for the period presented.

~~(2) Basis swap contracts establish a fixed amount for the differential between Argus WTI and Argus LLS prices on a trade-month basis for the period indicated.~~

During October 2019, the Company entered into additional oil swaps for January through December of 2021, which hedge 365,000 bbls at $51.69 per bbl. During November 2019, the Company entered into additional natural gas swaps for January through December of 2021, which hedge 1,830,000 MMcf at an average price of $2.54 per Mcf.

As of ~~September 30, 2019,~~March 31, 2020, all of the Company’s economic derivative hedge positions were with large financial institutions, which are not known to the Company to be in default on their derivative positions. The Company is exposed to credit risk to the extent of non-performance by the counterparties in the derivative contracts discussed above; however, the Company does not anticipate non-performance by such counterparties. None of the Company’s derivative instruments contain credit-risk related contingent features.

~~Note 4. Leases~~

~~Effective January 1, 2019, the Company adopted the new lease accounting standard (see~~ ~~Recent Accounting Pronouncements~~ in Note 1. above) using the modified retrospective method of applying the new standard at the adoption date. Adoption of this standard resulted in the recording of net operating lease ROU assets and corresponding operating lease liabilities of $0.3 million. Leases for reporting periods beginning on or after January 1, 2019 are presented under the new guidance, while prior periods amounts are not adjusted and continue to be reported in accordance with previous guidance.

Operating lease ROU assets are presented within Other Property and Equipment on the unaudited condensed consolidated balance sheet as of September 30, 2019. The current portion of operating lease liabilities are presented within Accrued Liabilities, and the non-current portion of operating lease liabilities are presented within Other Non-Current Liabilities on the unaudited condensed consolidated balance sheet.

Operating lease ROU assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Company's leases do not provide an implicit rate, the Company uses an incremental collateralized borrowing rate based on the information available at commencement date, including lease term, in determining the present value of future payments. The operating lease ROU asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. The Company's lease

terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term.

~~The Company's operating lease portfolio includes field equipment such as compressors and amine units, office space and office equipment. The Company currently does not have any financing leases.~~

Our compressor and amine unit arrangements are typically structured with a non-cancelable primary term of one to two-years and continue thereafter on a month-to-month basis subject to termination by either party with thirty days notice. The Company's compressor and amine unit rental agreements represent operating leases with a lease term that equals the primary non-cancelable contract term. Upon completion of the primary term, both parties have substantive rights to terminate the lease. As a result, enforceable rights and obligations do not exist under the rental agreement subsequent to the primary term.

The Company enters into daywork contracts for drilling rigs with third parties to support its drilling activities. The drilling rig arrangements are typically structured with a term that is in effect until drilling operations are completed on a contractually-specified well or well pad. Upon mutual agreement with the contractor, the Company typically has the option to extend the contract term for additional wells or well pads by providing thirty days notice prior to the end of the original contract term. Drilling rig arrangements represent short-term operating leases. The accounting guidance requires the Company to make an assessment at contract commencement if it is reasonably certain that it will exercise the option to extend the term.

Due to the continuously evolving nature of the Company's drilling schedules and the potential volatility in commodity prices in an annual period, the Company's strategy to enter into shorter term drilling rig arrangements allows it the flexibility to respond to changes in our operating and economic environment. The Company exercises its discretion in choosing to extend or not extend contracts on a rig-by-rig basis depending on the conditions present at the time the contract expires. At the time of contract commencement, the Company has determined it cannot conclude with reasonable certainty if it will choose to extend the contract beyond its original term. Pursuant to the successful efforts method of accounting, these costs are capitalized as part of natural gas and oil properties on our balance sheet when paid.

The Company leases a small part of the corporate building it owns a third-party, with a lease term that ends in 2023 and is non-cancelable. Third-party leasing income is insignificant and is included in Acquisition Costs and Other on the unaudited condensed consolidated statements of operations.

~~The components of our total lease expense for the three and nine months ended September 30, 2019 are as follows:~~

In thousands Three Months Ended September 30, 2019 Nine Months Ended September 30, 2019
Operating Leases $ 68
$ 205
Short-term leases⁽¹⁾
799
2,058
Total lease expense $ 867
$ 2,263
Short-term lease costs capitalized to oil and gas properties⁽²⁾
$ 4,904
$ 9,827

(1) Short-term leases represent expenses related to leases with a contract term of one year or less. The majority of these leases relate to field operating equipment and are included in lease operating and gas gathering expense on the unaudited condensed consolidated statement of operations.

(2) Short-term lease costs represent leases with a contract term of one year or less, the majority of which are related to drilling rigs and are capitalized as part of Oil and Gas Properties on the unaudited condensed consolidated balance sheets.

~~Supplemental balance sheet information related to leases follows:~~

In thousands, except lease term and discount rate data September 30, 2019
Operating leases
Assets
Other property and equipment $ 112
Liabilities
Accrued liabilities $ 112
Weighted-average remaining lease term (years) 0.4
Weighted-average discount rate 5.0 %

~~Supplemental cash flow information related to leases follows:~~

In thousands Nine Months Ended September 30, 2019
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases $ 205
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $ 205

The table below reconciles the undiscounted cash flows for each of the first five years and total of the remaining years to the operating lease liabilities recorded on the unaudited condensed consolidated balance sheet as of September 30, 2019:

In thousands Operating Leases
2019 $ 68
2020 45
Thereafter —
Total minimum lease payments 113
Amount of lease payments representing interest (1 )
Present value of future minimum lease payments $ 112

Under the previous accounting standard, future minimum lease payments for operating leases having initial or remaining noncancelable terms in excess of one year would have been as follows as of September 30, 2019:

In thousands Amount
2019 $ 174
2020 477
2021 368
Total minimum lease payments $ 1,019

Note 5.4. Revenue Recognition

The Company recognizes revenue when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.

Disaggregation of Revenue

Operating revenues are comprised of sales of crude oil, NGLs and natural ~~gas, as presented in the accompanying unaudited consolidated statements of operations for the three and nine months ended September 30, 2019 and 2018.~~

~~Accounting Policies~~

gas. Revenue is recognized when performance obligations under the terms of a contract with a customer are satisfied. The Company recognizes revenue when control has been transferred to the customer, generally at the time commodities reach an agreed-upon delivery point. Revenue is measured as the amount of consideration the Company expects to receive in exchange for transferring products and is generally based upon a negotiated formula, list or fixed price based on a market index. Typically, the Company sells its products directly to customers generally under agreements with payment terms less than 30 days.

~~Oil Revenues~~

The Company's crude oil sales contracts are generally structured such that Lonestar commits and dedicates for sale a specified volume of oil production from agreed-upon leases to a purchaser. Oil is sold at a contractually-specified index price plus or minus a differential, and title and control of thefollowing table summarizes our revenues by product generally transfers at the delivery point specified in the contract, at which point related revenue is recognized. For those leases in which Lonestar operates with other working interest owners, the Company recognizes oil revenue proportionate to its entitled share of volumes sold. Currently, all of Lonestar’s oil production comes from the Eagle Ford Shale play in South Texas, and direct sales to four purchasers accounttype for the ~~majority of its oil sales.~~three months ended March 31, 2020 and 2019:



In thousands	Three Months Ended March 31,
In thousands	2020		2019
Oil	$	29,990	$	33,584
NGLs	2,599		3,393
Natural gas	4,420		3,764
Total revenues	$	37,009	$	40,741

~~The Company’s oil purchase contracts are generally written to provide month-to-month terms with a 30-day cancellation notice. Sales~~As of ~~Lonestar’s oil production are typically invoiced monthly based on actual volumes measured at~~March 31, 2020 and December 31, 2019 the ~~agreed-upon delivery point and stated contract pricing for the month.~~

~~NGLs and Natural Gas Revenues~~

~~The Company’s NGL and natural gas purchase contracts are generally structured such that Lonestar commits and dedicates for sale a specified volume of NGL and/~~accounts receivable balance representing amounts due or natural gas production per day from agreed-upon leases to a purchaser. NGLs and natural gas are sold at a percentage of index prices of each component less any stated deductions. Control transfers at the delivery point specified in the contract, which typically is stated as the inlet or tailgate of a plant where the produced NGLs and natural gas are processed for subsequent transportation and consumption. In certain situations, Lonestar takes processed natural gas in-kind from a processing plant for sale under a separate purchase agreement with a different delivery point. The stated delivery point determines whether certain conditioning, treating, transportation and fractionation fees associated with the sold NGLs and natural gas are treated as operating expenses (occurring before the delivery point) or as deductions to revenues (occurring after the delivery point).

For those leases in which Lonestar operates with other working interest owners, the Company recognizes NGL and natural gas revenue proportionate to its entitled share of volumes sold. Currently, all of Lonestar’s NGL and natural gas production comes from the Eagle Ford Shale play in South Texas. Sales of Lonestar’s NGL and natural gas production is typically invoiced monthly based on actual volumes at the agreed-upon delivery point and stated contract pricing and allocations for the month.

Lonestar uses a third-party broker for its NGL and natural gas marketing. In this capacity, the third-party is responsible for carrying out marketing activities such as submission of nominations, receipt of payments, submission of invoices and negotiation of contracts. In this agreement, Lonestar retains final approval of contracts and is not entitled to sales proceeds from the third-party until they are collected from the related purchasers. Commissions payable to the third-party broker for these services are treated as operating expenses in the financial statements.

~~Production Imbalances~~

Revenue is recorded based on the Company’s share of volumes sold, regardless of whether the Company has taken its proportional share of volumes produced. A receivable or liability is recognized only to the extent that the Company has an imbalance on a specific property greater than the expected remaining proved reserves. There were no imbalances at September 30, 2019.

~~Significant Judgements~~

As noted above, the Company engages in various types of transactions in which midstream entities process its gas and subsequently market resulting NGLs and residue gas to third-party customers on Lonestar’s behalf. These types of transactions require judgement to determine whether Lonestar is the principal or the agent in the contract and, as a result, whether revenues are recorded gross or net.

~~The Company has determined that each unit of product represents a separate performance obligation~~billable under the terms of ~~its purchase~~ contracts with purchasers was $10.2 million and therefore, future volumes are wholly unsatisfied. Therefore, the Company has utilized the practical expedient exempting a Company from disclosure of the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation.

~~Prior-Period Performance Obligations~~

The Company records revenue in the month production is delivered to the purchaser. Settlement statements for certain NGL and natural gas sales may not be received for 30 to 60 days after the date production is delivered, and as a result, Lonestar is required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product.

The Company records the differences between its estimates and the actual amounts received for product sales in the month that payment is received from the purchaser. Any identified differences between its revenue estimates and actual revenue received historically have not been significant. For the nine months ended September 30, 2019, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material.

~~Accounts Receivable and Other~~

Accounts receivable – Oil, natural gas liquid and natural gas sales consist of amounts due from purchasers for commodity sales from our Eagle Ford fields. Payments from purchasers are typically due by the last day of the month following the month of delivery. There was no bad debt expense for any period presented, and an allowance for uncollectible accounts is unnecessary. The Company’s operations do not result in any contract assets or liabilities on the accompanying consolidated balance sheets.$16.0 million, respectively.

Note 6.5. Fair Value Measurements

Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company’s own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. ASC 820 prioritizes the inputs used in measuring fair value into the following fair value hierarchy:

Level 1 – Quoted prices for identical assets or liabilities in active markets.

Level 2 – Quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability, and inputs derived principally from or corroborated by observable market data by correlation or other means.

Level 3 – Unobservable inputs for the asset or liability. The fair value input hierarchy level to which an asset or liability measurement falls in its entirety is determined based on the lowest level input that is significant to the measurement in its entirety.

The following table presents the Company’s assets and liabilities that are measured at fair value on a recurring basis as of ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, for each fair value hierarchy level:

Fair Value Measurements Using
In thousands
Quoted Prices in Active Markets
(Level 1)

Significant Other Observable Inputs
(Level 2)

Significant Unobservable Inputs
(Level 3)
Total
September 30, 2019
Assets
Commodity derivatives $ —
$ 25,655
$ —
$ 25,655
Liabilities:
Commodity derivatives —
(3,275 ) —
(3,275 )
Warrant —
—
(461 ) (461 )
Stock-based compensation (1,287 ) —
(579 ) (1,866 )
Total $ (1,287 ) $ 22,380
$ (1,040 ) $ 20,053

December 31, 2018
Assets:
Commodity derivatives $ —
$ 23,143
$ —
$ 23,143
Liabilities:
Commodity derivatives —
(451 ) —
(451 )
Warrant —
—
(1,055 ) (1,055 )
Stock-based compensation (1,267 ) —
(636 ) (1,903 )
Total $ (1,267 ) $ 22,692
$ (1,691 ) $ 19,734

~~Commodity Derivatives~~

The Company's commodity derivatives represent non-exchange-traded oil and natural gas fixed-price swaps that are based on NYMEX pricing and fixed-price basis swaps that are based on regional pricing other than NYMEX (e.g., Louisiana Light Sweet). The asset and liability measurements for the Company's commodity derivative contracts represent Level 2 inputs in the hierarchy, as they are valued based on observable inputs other than quoted prices.

~~Warrants~~

The fair value of the Company's warrants is based on Black-Scholes valuations. In addition to the Company's observable stock price, other significant inputs are considered unobservable, and the Company has designated these estimates as Level 3.

~~Stock-Based Compensation~~

The Company's stock-based compensation includes the liability associated with restricted stock units ("RSUs") and stock appreciation rights ("SARs") dependent on the fair value of Lonestar's publicly-traded common stock. The fair value of RSUs is measured based on measurable prices on a major exchange; the significant inputs to these asset exchange values represented Level 1 independent active exchange market price inputs. The Black-Scholes model used to determine the fair value of the SARs uses inputs, in addition to the Company's observable stock price, that are considered unobservable; to this end the Company has designated these estimates as Level 3. See Note 10. ~~Stock-Based Compensation, below for more information.~~



	Fair Value Measurements Using
In thousands	Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
March 31, 2020
Assets
Derivative financial instruments	$	—		$	99,859		$	—		$	99,859
Liabilities:
Derivative financial instruments	—			(3,397		)	—			(3,397		)
Warrant	—			—			(1		)	(1		)
Stock-based compensation	(77		)	—			(27		)	(104		)
Total	$	(77	)	$	96,462		$	(28	)	$	96,357

December 31, 2019
Assets:
Derivative financial instruments	$	—		$	6,849		$	—		$	6,849
Liabilities:
Derivative financial instruments	—			(10,462		)	—			(10,462		)
Warrant	—			—			(364		)	(364		)
Stock-based compensation	(1,792		)	—			(573		)	(2,365		)
Total	$	(1,792	)	$	(3,613	)	$	(937	)	$	(6,342	)

Level 3 ~~Gains and Losses~~Fair Value Measurements

The table below sets forth a summary of changes in the fair value of the Company’s Level 3 liabilities for the ~~nine~~three months ended ~~September 30, 2019:~~March 31, 2020:

In thousands Warrant Stock-Based Compensation Total
Balance as of December 31, 2018 $ (1,055 ) $ (636 ) $ (1,691 )
Unrealized gains 594
57
651
Balance as of September 30, 2019 $ (461 ) $ (579 ) $ (1,040 )

~~Assets and liabilities measured at fair value on a nonrecurring basis~~

Non-recurring fair value measurements include certain non-financial assets and liabilities as may be acquired in a business combination and thereby measured at fair value; impaired oil and natural gas property assessments; warrants issued in debt or equity offerings and the initial recognition of asset retirement obligations for which fair value is used. These estimates are derived from historical costs as well as management’s expectation of future cost environments. As there is no corroborating market activity to support the assumptions used, the Company has designated these estimates as Level 3.



In thousands	Warrant			Stock-Based Compensation			Total
Balance as of December 31, 2019	$	(364	)	$	(573	)	$	(937	)
Unrealized gains	363			546			909
Balance as of March 31, 2020	$	(1	)	$	(27	)	$	(28	)

Other fair value measurements

The book values of cash and cash equivalents, accounts receivable and accounts payable, approximate fair value due to the short-term nature of these instruments. The carrying value of the Credit Facility (as defined in Note 8.7. below) approximates fair value since it is subject to a short-term floating interest rate that approximates the rate available to the Company. The fair value of the 11.25% Senior Notes (as defined in Note 8. below) was approximately ~~$214.8~~$64.1 million as of ~~September 30, 2019~~March 31, 2020 and ~~are~~is considered a Level 3 liability, as they are based on market transactions that occur infrequently as well as internally generated inputs.

Note 7.6. Accrued Liabilities

Accrued liabilities consisted of the following as of the dates indicated:


In thousands	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Accrued interest – 11.25% Senior Notes					$	7,031	$	14,063
Accrued well costs					12,387		8,932
Bonus payable	$	1,744	$	3,244	609		2,353
Payroll payable	51		773
Accrued interest – 11.25% Senior Notes	7,031		14,063
Accrued interest – other	478		104
Accrued well costs	3,074		9,026
Third party payments for joint interest expenditures	140		—
Accrued severance, property and franchise taxes	2,356		96
Accrued federal income tax	439		441
Current portion of operating lease liability	112		—
Other	675		381		3,022		1,557
Total accrued liabilities	$	16,100	$	28,128	$	23,049	$	26,905

Note 8.7. Long-Term Debt

The following long-term debt obligations were outstanding as of the dates indicated:


In thousands	September 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
Senior Secured Credit Facility	$	245,000		$	183,000		$	267,000		$	247,000
11.25% Senior Notes due 2023	250,000			250,000			250,000			250,000
Mortgage debt	8,959			9,151			8,877			8,931
Other	266			275			271			271
Total long-term debt	504,225			442,426			526,148			506,202
Unamortized discount	(3,656		)	(4,500		)	(3,094		)	(3,375		)
Unamortized debt issuance costs	(797		)	(1,044		)	(647		)	(759		)
Total long-term debt, net of debt issuance costs	$	499,772		$	436,882
Total net of debt issuance costs							522,407			502,068
Less current obligations							(513,259		)	(247,000		)
Long-term debt							$	9,148		$	255,068

Senior Secured Credit Facility

In July 2015, ~~the Company,~~ through its subsidiary, Lonestar Resources America, Inc. ("LRAI"), the Company entered into a $500 million Senior Secured Credit Facility with Citibank, N.A., as administrative agent, and other lenders party thereto (as amended, supplemented or modified from time to time, the “Credit Facility”), which has a maturity date of November 15, 2023. As of ~~September 30, 2019, $245.0~~March 31, 2020, $267.0 million was borrowed under the Credit Facility, and the weighted average interest rate on borrowings under the Credit Facility for the quarter was ~~5.32%~~5.30%. Borrowing availability was ~~$44.6~~$22.6 million as of ~~September 30, 2019,~~March 31, 2020, which reflects $0.4 million of letters of credit outstanding.

The Credit Facility may be used for loans and, subject to a $2.5 million sub-limit, letters of credit, and provides for a commitment fee of 0.375% to 0.5% (0.5% following the Thirteenth Amendment (as defined below)) based on the unused portion of the borrowing base under the Credit Facility. As of ~~September 30, 2019,~~March 31, 2020, the borrowing base and lender commitments for the Credit Facility was $290 million. The borrowing base was lowered to $286 million on June 11, 2020 as part of the Thirteenth Amendment. The borrowing base was further lowered to $225 million from $286 million pursuant to the Forbearance Agreement on July 2, 2020, creating a deficiency between the outstanding amount borrowed under our revolving credit facility and the borrowing base. The outstanding balance under our credit facility was $285 million as of July 2, 2020 which represents a borrowing deficiency of $60.4 million. We are obligated to pay the deficiency within 60 days after July 2, 2020, due to the Credit Facility's status of default (see below).

Borrowings under the Credit Facility, at the Company's election, bear interest at either: (i) an alternate base rate (“ABR”) equal to the higher of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus 0.5% per annum, and (c) the adjusted LIBO rate of a three-month interest period on such day plus 1.0%; or (ii) the adjusted LIBO rate, which is ~~determined semi-annually~~the rate stated on Reuters screen LIBOR1 page, for one, two, three, six or twelve months, as adjusted for statutory reserve requirements for Eurocurrency liabilities, plus, in each of ~~May 1 and November 1. As of November 11, 2019,~~ the ~~November 1 determination was ongoing and the prospective borrowing base amount had not been concluded upon with the lenders.~~

~~In June 2019, the Company entered into the Borrowing Base Redetermination and Tenth Amendment to Credit Agreement (the "Tenth Amendment"), which~~cases described in clauses (i) ~~increased the borrowing base from $275 million to $290 million~~ and (ii) ~~amended certain other provisions of~~above, an applicable margin ranging from 1.0% to 2.0% (2.0% to 3.5% following the Thirteenth Amendment) for ABR loans and from 2.0% to 3.0% (3.0% to 4.5% following the Thirteenth Amendment) for adjusted LIBO rate loans.

As the Credit Facility is in a state of default, 2.0% incremental default interest would typically be due but is currently not being charged as ~~set forth more specifically~~part of the terms of the Forbearance Agreement (see below).

Subject to certain permitted liens, the Company's obligations under the Credit Facility are required to be secured by the grant of a first priority lien on no less than 80% of the value of the proved oil and gas properties of the Company and its subsidiaries (currently 100% following the Thirteenth Amendment).

The Credit Facility contains certain financial performance covenants, as defined in the ~~Tenth Amendment.~~Credit Facility, including the following:

A maximum debt to EBITDAX ratio of 4.0 to 1.0, and

A current ratio of not less than 1.0 to 1.0.

The Company also was not in compliance with the terms of the Credit Facility as of ~~September 30,~~December 31, 2019 because it did not satisfy the consolidated current ratio at those times and the audit report prepared by its auditors with respect to the financial statements in the 2019 Form 10-K included an explanatory paragraph expressing uncertainty as to the Company's ability to continue as a "going concern." The lenders waived the current ratio default with respect to December 31, 2019. The Company received a forbearance until July 31, 2020 for the defaults in the consolidated current ratio covenant as of the March 31, 2020 measurement date and the missed interest payment under the 11.25% Senior Notes pursuant to the Forbearance Agreement. Despite the forbearance, the defaults under the Credit Facility are continuing, and will continue, absent a waiver from the lenders. The Company was not in compliance with the terms of the Credit Facility as of May 15, 2020, because it did not timely deliver its financial statements with respect to the fiscal quarter ended March 31, 2020. Such failure represented a default under the Credit Facility which the lenders waived pursuant to the Thirteenth Amendment. As noted above, the borrowing base was redetermined to $225 million from $286 million pursuant to the Forbearance Agreement on July 2, 2020, which created a deficiency between the outstanding amount borrowed under our revolving credit facility and the borrowing base. The outstanding balance under the Company's Credit Facility was $285 million as of July 2, 2020 which represents a borrowing deficiency of $60 million. The Company is obligated to pay the deficiency within 60 days after July 2, 2020.

Waiver and Eleventh Amendment

Effective April 7, 2020, the Company entered into the Waiver and Eleventh Amendment (the "Waiver") to waive events of default arising from its failure to comply with the consolidated current ratio as of December 31, 2019, to timely provide audited financial statements and to provide financial statements that are not subject to any “going concern” or like qualification or exception for the fiscal year ended December 31, 2019. As there was no guarantee that the Company's lenders would agree to waive events of default or potential events of default in the future, the amounts outstanding under the Credit Facility as of December 31, 2019 were classified as current in the accompanying 2019 Condensed Consolidated Balance Sheet.

Twelfth Amendment

Effective May 8, 2020, the Company entered into the Twelfth Amendment to Credit Agreement (the “ Twelfth Amendment”), to allow the Company to accept proceeds of up to $2.2 million from an unsecured loan applied for under the Coronavirus Aid, Relief and Economic Security Act (as discussed further in Note 1).

Waiver and Thirteenth Amendment

Effective June 11, 2020, the Company entered into the Waiver and Thirteenth Amendment to Credit Agreement (the "Thirteenth Amendment") which, among other things, (i) waived any default or event of default arising from its failure to provide timely quarterly financial statements for the three months ended March 31, 2020; (ii) redetermined the borrowing base to $286 million from $290 million; (iii) set the next borrowing base redetermination to be on or around July 1, 2020 (and in any event, no later than July 31, 2020), (iv) amended the borrowing base utilization grid used in the applicable margin, as noted above and (v) until the July 1, 2020 redetermination, restricted the Company and its subsidiaries’ ability to incur debt with respect to, among other items, capital leases and permitted senior debt, grant liens to secure other obligations, pay dividends on LRAI’s preferred stock and make certain investments.

~~Issuance~~

As there is no guarantee that the Company's lenders will agree to waive events of default or potential events of default in the future, the amounts outstanding under the Credit Facility as of March 31, 2020 were classified as current in the accompanying Condensed Consolidated Balance Sheet.

Forbearance Agreement and Fourteenth Amendment

On July 2, 2020, the Company entered into a Forbearance Agreement, Fourteenth Amendment, and Borrowing Base Agreement with Citibank, N.A., as administrative agent and the lenders party thereto (the “Forbearance Agreement”) with respect to the Credit Facility. Pursuant to the Forbearance Agreement, among other things, (i) the lenders under the Credit Facility agree to refrain from exercising their rights and remedies under the Credit Facility and related loan documents with respect to certain defaults until July 31, 2020, (ii) the borrowing base was redetermined to $225 million from $286 million, (iii) all proceeds of dispositions and terminations or liquidations of swap agreements shall be used to repay the Credit Facility and shall automatically reduce the borrowing base by the amount of the repayment and (iv) certain exceptions to the covenant restriction on investments shall no longer be available.

The rights of the lenders to exercise rights and remedies resulted from our failure to comply with the current ratio with respect to the quarter ended March 31, 2020 and the defaults expected with respect to the quarter ending June 30, 2020, under the current ratio and the leverage ratio covenants, and the default with respect to the failure to make the interest payment due on July 1, 2020, under the 11.25% Senior Notes.

The Forbearance Agreement can be terminated by the lenders upon (i) the occurrence of any default or event of default under the Credit Facility other than those disclosed, (ii) the failure of the Company to comply with any of the terms and requirements of the Forbearance Agreement, (iii) the breach of any representation or warranty, (iv) the exercise of any rights by other debt holders relating to foreclosure or acceleration and (v) the commencement of any bankruptcy proceeding with respect to any loan party. Additionally, the Forbearance Agreement can be terminated if the Company fails to deliver a detailed restructuring proposal to the lenders by July 16, 2020. If the Forbearance Agreement terminates and any then-current and ongoing events of default have not been waived or cured, the lenders will be able to accelerate the loans and pursue their rights and remedies.

11.25% Senior Notes

In January 2018, the Company issued $~~250~~$250 million of ~~11.250% senior notes due 2023 (the “11.25%~~11.25% Senior ~~Notes”)~~Notes to U.S.-based institutional investors. The net proceeds of $~~244.4~~$244.4 million were used to fully retire the Company’s 8.75% Senior Notes, ~~(as defined below),~~ which included principal, interest and a prepayment premium of approximately $~~162~~$162 million. The remaining net proceeds were used to reduce borrowings under the Credit Facility.

The 11.25% Senior Notes mature on January 1, 2023, and bear interest at the rate of 11.25% per year, payable on January 1 and July of each year. At any time prior to January 1, 2021, the Company may, on any one or more occasions, redeem up to 35% of the aggregate principal amount of the 11.25% Senior Notes with an amount of cash not greater than the net cash proceeds of certain equity offerings at a redemption price equal to 111.25% of the principal amounts redeemed, plus accrued and unpaid interest, provided that at least 65% of the aggregate principal amount of 11.25% Senior Notes originally issued remains outstanding immediately after such redemption and the redemption occurs within 180 days of the closing date of such equity offering.

At any time prior to January 1, 2021, the Company may, on any one or more occasions, redeem all or a part of the 11.25% Senior Notes at a redemption price equal to 100% of the principal amount redeemed, plus a “make-whole” premium as of, and accrued and unpaid interest.

On and after January 1, 2021, the Company may redeem the 11.25% Senior Notes, in whole or in part, plus accrued and unpaid interest, at the following redemption prices: 108.438% after January 1, 2021; 105.625% after January 1, 2022; and 100% after July 1, 2022.

The Company did not make its interest payment on the 11.25% Senior Notes that was due on July 1, 2020 of approximately $14.1 million. The Company has 30 days to cure the default before the holders of the 11.25% Senior Notes or the trustee may be able to accelerate payment. The missed interest payment is a current event of default under the Credit Facility. The Company has entered into the Forbearance Agreement which provides that, among other things, the lenders under the Credit Facility have agreed to forbear the Company’s default of the interest payment until July 31, 2020. However, the default under the Credit Facility has not been waived and still exists, and the Forbearance Agreement can be terminated if the Company fails to deliver a detailed restructuring proposal to the lenders by July 16, 2020. Accordingly, the amounts outstanding under the 11.25% Senior Notes as of March 31, 2020 were classified as current in the accompanying Condensed Consolidated Balance Sheet.

The indenture contains certain restrictions on the Company’s ability to incur additional debt, pay dividends on the Company’s common stock, make investments, create liens on the Company’s assets, engage in transactions with affiliates, transfer or sell assets, consolidate or ~~merger,~~merge, or sell substantially all of the Company’s assets.

~~Retirement of 8.75% Senior Notes~~

~~Using proceeds from the issuance~~ The indenture also contains cross-default provisions for defaults of the ~~11.25% Senior Notes, as discussed above,~~Company's other debt instruments, including the ~~Company fully retired~~Credit Facility, caused by payment default or events which cause the ~~8.750% Senior Unsecured Notes due April 15, 2019 (“the 8.75% Senior Notes”) in January 2018. Pursuant~~acceleration of repayment prior to the ~~terms~~stated maturity of ~~the indenture, the 8.75% Senior Notes were redeemed at 104.375% of the outstanding principal amount, or approximately $158.5~~ ~~million, which excluded accrued interest. In connection with this transaction, the Company recognized a $8.6 million loss on extinguishment during the first quarter of 2018.~~such instrument.

~~Debt Issuance Costs~~

The Company ~~capitalizes certain direct costs associated with~~cannot provide any assurances that it will be successful in restructuring existing debt obligations or in obtaining capital sufficient to fund the ~~issuance~~refinancing of ~~long-term debt~~its outstanding indebtedness or to provide sufficient liquidity to meet its operating needs. If the Company is unsuccessful in its efforts to restructure and ~~amortizes such costs over~~obtain new financing, it may be necessary for the ~~lives~~Company to seek protection from creditors under Chapter 11 of the ~~respective debt. At September 30, 2019 and December 31, 2018,~~U.S. Bankruptcy Code (“Chapter 11”), or an involuntary petition for bankruptcy may be filed against the Company had approximately $1.0 million and $1.7 million, respectively, of debt issuance costs associated with issuance of the Credit Facility remaining that are being amortized over the lives of the respective debt which are recorded as Other Non-Current Assets in the accompanying unaudited condensed consolidated balance sheets.Company.

Note 9.8. Stockholders’ Equity

Series A ~~& B Preferred Stock~~

In June 2017, the Company closed on acquisitions with Battlecat Oil & Gas, LLC ("Battlecat") and SN Marquis LLC ("Marquis"). In connection with financing the Battlecat and Marquis Acquisitions, the Company issued ~~5,400~~ ~~shares of Series A-1 Convertible Participating~~ Preferred Stock ~~par value $0.001 per share (the “Series A-1 Preferred Stock”) and~~ ~~74,600~~ shares of Series A-2 Convertible Participating Preferred Stock, par value $0.001 per share (the “Series A-2 Preferred Stock” and, together with the Series A-1 Preferred Stock, the “Series A Preferred Stock”), to Chambers Energy Capital (“Chambers”). Also in June 2017, in connection with the Battlecat and Marquis Acquisitions, the Company issued ~~1,184,632~~ ~~and~~ ~~1,500,000~~ ~~shares of Series B Preferred Stock to Battlecat and Marquis.~~

As a result of the stockholder approval obtained in November 2017, all outstanding Series A-2 Preferred Stock was converted to Series A-1 Preferred Stock. Also, on November 3, 2017, in accordance with the terms of the Series B Certificate of Designations, all of the outstanding shares of the Company’s Series B Preferred Stock were converted on a one-for-one basis into shares of the Company’s Class A voting common stock.

After the Chambers agreement closing, and for so long as the Approved Holders (as defined) beneficially own at least 10% of the total number of outstanding shares of Class A voting common stock and Class B non-voting common stock (collectively, “Common Stock”) of the Company, on an as-converted basis, or at least 15% of the number of Series A Preferred Stock issued to Chambers, the Company cannot undertake certain actions without the prior consent of holders of a majority of all shares of Common Stock, on an as-converted basis, held by the Approved Holders. Prior to June 15, 2020, Chambers and its affiliates are prohibited from directly or indirectly engaging in any short sales involving the Common Stock or securities convertible into, or exercisable or exchanged for, Common Stock. Without the prior written consent of the board, the Approved Holders are subject to customary standstill restrictions until the earlier of (i) the two-year anniversary of the date the Approved Holders are no longer entitled to designate any director to the Board and (ii) the date the Company fails to fully declare and pay all accrued dividends on either series of the Series A Preferred Stock after there are no PIK Quarters (as defined below) remaining. In connection with the closing and the issuance of shares of Series A Preferred Stock, the Company entered into a registration rights agreement with Chambers (the “Chambers RRA”). Under the Chambers RRA, the Company has agreed to provide to Chambers certain customary demand and piggyback registration rights relating to Chambers’ ownership of Company stock. The Chambers RRA contains customary terms and conditions, including certain customary indemnification obligations.

The Series A-1 Preferred Stock ranks senior to Class A voting common stock with respect to dividend rights and rights upon the liquidation, winding-up or dissolution of the Company, and the series initially has a stated value of $1,000 per share. Holders of Series A-1 Preferred Stock are entitled to vote with holders of Class A voting common stock on an as-converted basis. Shares of Series A-1 Preferred Stock are convertible into shares of Class A voting common stock at the option of the holders of such Series A-1 Preferred Stock at a per share rate (the “Conversion Rate”) equal to the Stated Value of such share divided by six, subject to certain adjustments (the “Conversion Price”). The Company has the option to convert Series A-1 Preferred Stock to Class A voting common stock if the volume weighted average price of Class A voting common stock exceeds the following percentages of the Conversion Price for twenty out of thirty consecutive trading days: (i) 175%, if such mandatory conversion occurs before June 15, 2020 and (ii) 150%, if such mandatory conversion occurs after June 15, 2020.Dividends

Holders of Series A-1 Preferred Stock are entitled to cumulative dividends payable quarterly initially at a rate of 9% per annum (the “Dividend Rate”) in cash and, for any 12 quarters (“PIK Quarters”), at the Company’s option, (i) in the form of additional shares of the respective series of Series A-1 Preferred Stock at a per share price equal to $975 or (ii) by increasing Stated Value, in lieu of cash (collectively, the “PIK Option”). After the 12 PIK Quarters ~~(three~~(one of which remain as of ~~September 30, 2019)~~March 31, 2020), if the Company fails to fully declare and pay dividends in cash, then the Dividend Rate for Series A Preferred Stock will automatically increase by 5% per annum for the next succeeding dividend period and then an additional 1% for each successive dividend period, up to a maximum Dividend Rate of 20% per annum, until the Company pays dividends at such increased rate fully in cash for two consecutive quarters. In addition to dividends rights described above, holders of the Series A-1 Preferred Stock are entitled to receive dividends or distributions declared or paid on Class A voting common stock on an as-converted basis. If on June 15, 2024, the Prevailing Price is less than the Conversion Price then in effect, the Dividend Rate for Series A-1 Preferred Stock will automatically increase to 20% per annum, payable only in cash, unless automatically converted as described above. However, the Company, at its option, may instead elect to exchange each share of Series A-1 Preferred Stock for senior unsecured notes of the Company

Starting with a two-year maturity, a 9% per annum coupon payable semi-annually in cash, and governed by terms substantially similar to the Company’s most recent high yield indenture at that time. After June 15, 2020, the Company may redeem shares of Series A-1 Preferred Stock in cash at a per share amount equal to (i) 110% of the Stated Value, if the redemption occurs prior to June 15, 2021, (ii) 105% of the Stated Value, if the redemption occurs on or prior to June 15, 2022, and (iii) 100% of the Stated Value, if the redemption occurs after June 15, 2022, in each case, plus any unpaid dividends.

~~For~~ the third ~~and fourth quarters~~quarter of 2017 and ~~all four quarters~~through the fourth quarter of ~~2018,~~2019, the Company elected the PIK Option for the Class A-1 Preferred Stock dividend payment, which resulted in the issuance of ~~11,784~~20,328 additional shares of Series A-1 Preferred Stock. ~~For~~During the first ~~three quarters~~quarter of ~~2019,~~2020, the Company also elected the PIK Option, ~~for the Class A-1 Preferred Stock dividend payment,~~ which resulted in the issuance of ~~6,336~~2,257 additional shares of Series A-1 Preferred Stock.

~~Repurchase and Retirement of Class B Common Stock~~

In connection with the EF Realisation liquidation in October 2018, the Company repurchased and retired 2,500 shares of the Class B non-voting common stock (the "Class B Stock") from Dr. Christopher Rowland at a cost of $10,000 on September 28, 2018. The Class B Stock was originally issued to Dr. Rowland in connection with the Company's reorganization in 2016. After the repurchase and retirement of the Class B Stock, there are no shares of Class B Stock issued and outstanding.

Note ~~10.~~9. Stock-Based Compensation

Restricted Stock Units

Lonestar grants awards of restricted stock units ("RSUs") to employees and directors as part of its long-term compensation program. The awards vest over a three-year period, with specific terms of vesting determined at the time of grant. The Company determined the fair value of granted RSUs based on the market price of the Class A voting common stock of the Company on the date of grant. RSUs are paid in Class A voting common stock or cash (see below) after the vesting of the applicable RSU. Compensation expense for granted RSUs is recognized over the vesting period. For the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ the Company recognized ~~$2.0~~$(1.3) million and ~~$2.1~~$0.7 million, respectively, of stock-based compensation (benefit) expense for RSUs.

During the first quarter of 2018, the Company elected to offer cash settlement to all employees for vested RSUs and, as a result of this modification, the RSU awards are classified as a liability on the Company’s balance sheet in accordance with ASC 718, ~~Compensation – Stock Compensation,~~ as of September 30, 2019 and December 31, 2018. As of the date of the modification, periodic compensation expense related to the awards is recognized based on the fair value of the awards, subject to a floor valuation that represents the compensation expense amount that would have otherwise been recognized had the Company not modified the terms of the award. The liability for RSUs on the accompanying consolidated balance sheet as of ~~September 30, 2019~~March 31, 2020 was ~~$1.3~~$0.1 million.

As of ~~September 30, 2019,~~March 31, 2020, there was ~~$3.7~~$0.4 million of unrecognized compensation expense related to non-vested RSU grants. This unrecognized compensation cost is expected to be recognized over a weighted-average period of ~~2.1~~1.7 years. ~~No RSUs~~The fair value of RSU grants that vested during the three months ended ~~September 30, 2019.~~March 31, 2020 and 2019 totaled 0.5 million and 0.9 million, respectively.

A summary of the status of the Company's non-vested RSU grants issued, and the changes during the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 is presented below:


	Shares		Weighted Average Fair Value per Share		Shares		Weighted Average Fair Value per Share
Non-vested RSUs at December 31, 2018	1,011,045		$	5.06
Non-vested RSUs at December 31, 2019					1,849,676		$	4.04
Granted	1,274,750		3.42		—		—
Vested	(434,900	)	4.64		(692,050	)	0.69
Forfeited	(3,450	)	—		(24,200	)	—
Non-vested RSUs at September 30, 2019	1,847,445		$	4.04
Non-vested RSUs at March 31, 2020					1,133,426		$	3.62

Stock Appreciation Rights

In the past, Lonestar has granted awards of stock appreciation rights (“SARs”) to employees and directors as part of its long-term compensation program. The awards vest over a three-year period, with specific terms of vesting determined at the time of grant, and expire five-years after the date of issuance. The SARs are granted with a strike price equal to the fair market value at the time of grant, which erally defined as the closing price of the Company's common stock on the NASDAQ on the date of grant. SARs will be paid in cash or common stock at holder’s election once the SAR is vested. For the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ the Company recognized ~~$(0.1)~~$(0.5) million and ~~$1.5~~$0.2 million, respectively, of stock-based compensation (benefit) expense for SARs. The liability for SARs on the accompanying unaudited consolidated balance sheet as of ~~September 30, 2019~~March 31, 2020 was ~~approximately $0.6 million.~~not material.

As of ~~September 30, 2019, there was $0.2 million of~~March 31, 2020, the total compensation cost to be recognized in future periods related to non-vested SAR ~~grants.~~grants was not material. The cost is expected to be recognized over a weighted-average period of 1.0 year.

The following is a summary of the Company's SAR activity:

Shares Weighted Average Exercise Price Per Share
Weighted Average Remaining Contractual Term
(in years)
Outstanding at December 31, 2018 1,010,000
$ 6.30
3.5
SARs vested and exercisable at December 31, 2018 280,000
7.20
3.2
Granted —
—
—
Exercised —
—
—
Expired/forfeited —
—
—
Outstanding at September 30, 2019 1,010,000
$ 6.30
2.8
SARs vested and exercisable at September 30, 2019 606,250
$ 6.65
2.7



	Shares	Weighted Average Exercise Price Per Share		Weighted Average Remaining Contractual Term (in years)
Outstanding at December 31, 2019	1,010,000	$	6.30	2.5
SARs vested and exercisable at December 31, 2019	606,250	6.65		2.4
Granted	—	—		—
Exercised	—	—		—
Expired/forfeited	—	—		—
Outstanding at March 31, 2020	1,010,000	$	6.30	2.3
SARs vested and exercisable at March 31, 2020	805,000	$	6.79	2.1

Note ~~11.~~10. Related Party Activities

~~Leucadia~~

In August 2016, Lonestar entered into a Securities Purchase Agreement (the “Purchase Agreement”) with Juneau, as initial purchaser, Leucadia as guarantor of Juneau’s obligations, the other purchasers party thereto and Jefferies, LLC, in its capacity as the collateral agent for the purchasers, relating to the issuance and sale of (i) up to $49.9 million aggregate principal amount of the Company's 12% senior secured second lien notes due 2021 (“Second Lien Notes”) and (ii) five-year warrants to purchase up to an aggregate 998,000 shares of the Company’s Class A voting common stock at a price equal to $5.00 per share (the “Warrants”). During 2016, the Company's issued ~~$25.0~~ million in aggregate principal amount of Second Lien Notes and the Company issued Warrants to purchase 500,000 shares of its Class A voting common stock to Juneau. In December 2016, LRAI repaid to Juneau $21.0 million principal of the Second Lien Notes.

In connection with entering into the Purchase Agreement, the Company also entered into a registration rights agreement and an equity commitment agreement. Pursuant to the registration rights agreement, the Company had agreed to register for resale certain Class A voting common stock issued or issuable to Juneau and Leucadia, including those issuable upon exercise of the Warrants. The Form S-3 registration statement was filed with the Securities and Exchange Commission on November 7, 2017 and is effective. Leucadia agreed, pursuant to the equity commitment agreement, to purchase a certain number of Class A voting common stock in case the Company elected to pursue an equity offering prior to December 31, 2016. Pursuant to the equity commitment agreement, Leucadia purchased 3,478,261 shares of Class A voting common stock (costing $20 million) through a common stock offering, which closed in December 2016. In connection with Leucadia’s equity commitment, the Company paid Leucadia in January 2017 a $1.0 million fee, which was recorded as a reduction to additional paid-in capital. In the event Leucadia purchased not less than its commitment amount, the Company agreed to use commercially reasonable efforts to enter into arrangements to provide Leucadia with the right to appoint one director to the Board of the Company, provided that such right will terminate at such time as Leucadia and its affiliates own a number of shares of Class A voting common stock equal to less than 50% of the shares purchased by Leucadia and its affiliates in such offering. Leucadia has elected to take an observer position on the board of directors, with no voting rights.

~~EF Realisation~~

In October 2016, Lonestar entered into a Board Representation Agreement (the “Board Representation Agreement”) with EF Realisation Company Limited (“EF Realisation”). Under the Board Representation Agreement, for as long as EF Realisation, together with its affiliates, beneficially owns 15% or more of the issued and outstanding shares of the Company’s Class A voting common stock, it has the right to nominate up to, but no more than, two directors to serve on the Board and for as long as EF Realisation, together with its affiliates, beneficially owns at least 10% but less than 15% of the Company’s issued and outstanding shares of Class A voting common stock, it has the right to nominate up to, but no more than, one director to serve on the Board.

On October 9, 2018, EF Realisation notified the Company that it had completed a voluntary liquidation and distribution of assets to certain of its shareholders, including the sale or distribution of all of EF Realisation's 4,174,259 shares of the Company's Class A Stock, representing approximately 17% of the Company's total Class A Stock outstanding at the time. Following the liquidation, EF Realisation is no longer a shareholder of the Company.

~~Amendment of Registration Rights Agreement~~

In connection with the Battlecat and Marquis acquisitions, in June 2017, Lonestar entered into (i) a first amendment to the registration rights agreement (the “Leucadia RRA Amendment”) with Leucadia and JETX Energy, LLC (f/k/a Juneau Energy, LLC), which amends the registration rights agreement by and among the same parties, and (ii) a first amendment to registration rights agreement (the “EF RRA Amendment” and, together with the Leucadia RRA Amendment, the “RRA Amendments”) with EF Realisation, which amends the registration rights agreement from October 2016 by and between the same parties. The RRA Amendments set forth the relative priorities, with respect to demand and piggyback registration rights, among each applicable party thereto, Battlecat, Marquis and Chambers under their respective registration rights agreements with the Company.

~~Other Related Party Transactions~~

New Tech Global Ventures, LLC, and New Tech Global Environmental, LLC, companies in which a director of the Company owns a limited partnership interest, have provided field engineering staff and consultancy services for the Company since 2013. The total cost for such services was approximately $0.5 million and ~~$0.6~~$0.3 million for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $1.3 million and $1.4 million for the nine months ended September 30, 2019 and 2018,~~ respectively.

In February 2019, the Company purchased a property adjacent to its corporate office for future expansion for approximately $2.0 million. The transaction was funded with cash from operations. The seller of the property is indebted to certain trusts established in favor of the children of one of the Company's directors. The Company understands that the seller may use some of the proceeds of the sale to satisfy such outstanding indebtedness, though the Company has no interest or influence over any particular outcome.

Note ~~12.~~11. Commitments and Contingencies

Lonestar has one drilling rig under contract that is currently operating, which provides for a drilling rate of ~~$22.5~~$19.0 thousand per day and expires on ~~March 22,~~September 7, 2020. Should the Company terminate the contract early, the early termination fee totals $15.0 thousand per day times the remaining number of days left on the contract after the termination date.

In November 2018, the Company signed a dedicated fleet contract that provides for hydraulic fracturing and wireline services at variable rates depending on the work performed. As amended, the contract provides for services for any wells the Company completes and expires on December 31, 2020 with no provisions for early termination.

From time to time, Lonestar is subject to legal proceedings and claims that arise in the ordinary course of business. Like other crude oil and gas producers and marketers, the Company's operations are subject to extensive and rapidly changing federal and state environmental, health and safety, and other laws and regulations governing air emissions, wastewater discharges and solid and hazardous waste management activities. The Company is not aware of any pending or overtly threatened legal action against it that could have a material impact on its business.

Gonzales County AMI

In February 2020, the Company announced that it had entered into a Joint Development Agreement (the "JDA") in Gonzales County with one of the largest producers in the Eagle Ford which encompass an Area of Mutual Interest (the "AMI") totaling approximately 15,000 acres.

The agreement calls for Lonestar to operate a minimum of three to four Eagle Ford Shale wells annually on behalf of the two companies through 2022 that are intended to hold-by-production approximately 6,000 gross acres within the AMI. The agreement gives Lonestar's partner the option to participate in each well with a 50% working interest or to participate via a carried working interest that ranges from approximately 9 to 17%, depending on location.

In June, the Company began flowback operations on the Hawkeye #14H, Hawkeye #15H, and Hawkeye #16H, which were the first wells completed in the AMI. The Company's JDA partner did not participate in these wells, and on June 29, 2020 the Company completed a sale of 40% of the working interest in these wells to a third party for $9.1 million. After the sale, Lonestar has a 50% WI / 37.5% NRI in these wells.

Note ~~13.~~12. Subsequent Events

~~None.~~Preferred Stock PIK Dividend

On June 25, 2020, the Company approved a dividend with respect to the Company’s Series A-1 Preferred Stock. Chambers, as the holder of A-1 Preferred Stock as of June 25, 2020, received an aggregate of 2,308 additional shares of A-1 Preferred Stock as a dividend for its A-1 Preferred Stock on June 30, 2020.

CIC Plan

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

The following discussion and analysis should be read in conjunction with our Unaudited Condensed Consolidated Financial Statements and Notes thereto included herein and our Consolidated Financial Statements and Notes thereto included in our Annual Report on Form 10-K for the year ended December 31, ~~2018~~2019 (the “Form 10-K”), along with Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in the Form 10-K. Any terms used but not defined herein have the same meaning given to them in the Form 10-K. Our discussion and analysis includes forward-looking information that involves risks and uncertainties and should be read in conjunction with Risk Factors under Item 1A of the Form 10-K, along with Forward Looking Information at the end of this section for information on the risks and uncertainties that could cause our actual results to be materially different than our forward-looking statements.

OVERVIEW

Lonestar is an independent oil and natural gas company focused on the exploration, development and production of unconventional oil, natural gas liquids and natural gas in the Eagle Ford Shale play in South Texas.

Market Developments and Response to Commodity Price Declines

The COVID-19 coronavirus ("COVID-19") pandemic has resulted in a severe worldwide economic downturn, significantly disrupting the demand for oil throughout the world, and has created significant volatility, uncertainty and turmoil in the oil and gas industry. The decrease in demand for oil combined with the oil supply increase attributable to the battle for market share among the Organization of the Petroleum Exporting Countries ("OPEC"), Russia and other oil producing nations, resulted in oil prices declining significantly beginning in late February 2020. During this time NYMEX oil prices declined from averages in the mid-$50s per Bbl range in January and February 2020, to an average of approximately $30 per Bbl in March. NYMEX oil prices continued to decline in April 2020 to an average of $17 per Bbl in response to uncertainty about the duration of the COVID-19 pandemic and storage constraints resulting from over-supply of produced oil, before recovering to the upper-$30s per Bbl by late June after the implementation of production cuts by OPEC, significant production cuts by domestic operators, and an easement of storage capacity concerns.

The length of this demand disruption is unknown, and there is significant uncertainty regarding the long-term impact to global oil demand, which will ultimately depend on various factors and consequences beyond our control, such as the duration and scope of the pandemic, the length and severity of the worldwide economic downturn, additional actions by businesses and governments in response to both the pandemic and the decrease in oil prices, the speed and effectiveness of responses to combat the virus, and the time necessary to equalize oil supply and demand to restore oil pricing.

In response to these developments, we have implemented the following operational and financial measures:

Reduced budgeted 2020 capital spending from $80-$85 million to $55-$65 million, or 27% at midpoint;

Deferred our 2020 drilling program;

Implemented cost-reduction measures including negotiating reduced rates for water disposal, chemicals, rentals, and workovers;

Shut in or stored approximately 4,700 BOE per day of production during late-April and all of May 2020, primarily at our oil-rich fields in our Central Eagle Ford Area. When the Company brought these shut-in wells back online during the first week of June, they came on stronger than before, producing an additional 500 BOE per day across all wells.

Entered into additional commodities derivatives in March 2020 to hedge an additional 2,000 Bbls of oil per day at an average swap price of $41.00 per Bbl and 27,500 Mcf of natural gas per day at an average price of $2.36 per Mcf in 2021. Our current oil hedge position covers 7,498 Bbls per day for the second quarter of 2020, 7,565 Bbls per day for the second half of 2020, and 7,000 Bbls per day for 2021. Our current natural gas hedge position covers 20,000 Mcf per day for the remaining three quarters of 2020, and 27,500 Mcf per day for 2021.

We continue to assess the global impacts of the COVID-19 pandemic and expect to continue to modify our plans as more clarity around the full economic impact of COVID-19 becomes available. See Risk Factors for further discussion of the adverse impacts of the COVID-19 pandemic on our business.

Recent Developments

Our present level of indebtedness and the current commodity price environment present challenges to our ability to comply with the covenants in our revolving credit facility over the next twelve months and therefore substantial doubt exists that we will be able to continue as a going concern. As of March 31, 2020, we had total indebtedness of $522.4 million, including $250.0 million of Senior Notes due 2023 (the "11.25% Senior Notes”), $267.0 million under our Credit Facility (as defined below) and $8.9 million under our building loan. At July 2, 2020, we had $285 million drawn on the Credit Facility and have a $60.4 million borrowing base deficiency due to the terms of the Forbearance Agreement (as defined below), which redetermined our borrowing base at $225 million.

We did not satisfy the consolidated current ratio covenant under our Credit Facility as of the March 31, 2020 and December 31, 2019 measurement dates and we defaulted on the July 1, 2020 interest payment under the 11.25% Senior Notes. Such failures represent events of default under our Credit Facility, and the missed interest payment will represent an event of default under the 11.25% Senior Notes if not cured in 30 days. In addition, the audit report prepared by our auditors with respect to the financial statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 2019 includes an explanatory paragraph expressing uncertainty as to our ability to continue as a “going concern.” This, in addition to not providing timely audited financial statements, represented an additional default under the Credit Facility. As a result, the outstanding amount of borrowings under the Credit Facility as of March 31, 2020 and December 31, 2019 have been classified as current in the accompanying consolidated balance sheets because we do not anticipate maintaining compliance with the consolidated current ratio over the next twelve months.

We entered into the Waiver (as defined below) on April 7, 2020, with certain lenders and Citibank, N.A., as administrative bank, to waive the events of default relating to our failure to comply with the current ratio covenant as of December 31, 2019, to provide timely audited financial statements and to provide audited financial statements that are not subject to any “going concern” or like qualification or exception for the fiscal year ended December 31, 2019. We entered into the Thirteenth Amendment on June 11, 2020 with the lenders to waive any default and event of default relating to our failure to timely deliver the quarterly financial statements for the three months ended March 31, 2020. Although we have entered into these waivers, there is no guarantee that our lenders will agree to waive events of default or potential events of default in the future. Our failure to meet the current ratio in the Credit Facility as of March 31, 2020, is an event of default under the Credit Facility. The Company received a forbearance until July 31, 2020 for the default in the consolidated current ratio covenant as of the March 31, 2020 measurement date and the default for the missed interest payment under the 11.25% Senior Notes pursuant to the Forbearance Agreement. Despite the forbearance, the defaults under the Credit Facility are continuing, and will continue, absent a waiver from the lenders.

As we do not anticipate maintaining compliance with the consolidated current ratio covenant under our revolving credit facility over the next twelve months, we are evaluating the available financial alternatives, including obtaining alternative financing as well as seeking waivers, forbearances or amendments to the covenants or other provisions of our revolving credit facility to address any existing or future defaults and have engaged financial and legal advisors to assist. If we are unable to reach an agreement with our lenders or find acceptable alternative financing, the lenders under our revolving credit facility may choose to accelerate repayment, which in-turn may result in an event of default and an acceleration of the 2023 Notes due to cross-default provisions. We have concluded that these circumstances create substantial doubt regarding our ability to continue as a going concern. If the Company's lenders or its noteholders accelerate the payment of amounts outstanding under its Credit Facility or the 11.25% Senior Notes, respectively, it does not currently have sufficient liquidity to repay such indebtedness and would need additional sources of capital to do so. While the Company believes the proceeds of assets sales can fund immediate working capital needs, in the context of the current market conditions it is unclear whether the Company can obtain any additional sources of capital. We have concluded that these circumstances create substantial doubt regarding our ability to continue as a going concern.

The Company cannot provide any assurances that it will be successful in restructuring existing debt obligations or in obtaining capital sufficient to fund the refinancing of its outstanding indebtedness or to provide sufficient liquidity to meet its operating needs. If the Company is unsuccessful in its efforts to restructure and obtain new financing, it may be necessary for the Company to seek protection from creditors under Chapter 11 of the U.S. Bankruptcy Code (“Chapter 11”), or an involuntary petition for bankruptcy may be filed against the Company.

Operational Highlights for the ~~Third~~First Quarter of ~~2019~~2020

During the ~~third~~first quarter of ~~2019,~~2020, we achieved the following operating and financial results:

~~Grew production~~Production increased by ~~45%~~27% compared to the ~~third~~first quarter of ~~2018,~~2019, averaging ~~18,097~~14,436 BOE per day versus ~~12,471~~11,372 BOE per day. Compared to the ~~second~~fourth quarter of 2019, production ~~grew 33%~~decreased 18%, or ~~4,467~~3,111 BOE per day, from ~~13,630~~17,547 BOE per day.

Delivered outstanding wellhead realizations during the quarter. Our wellhead crude oil price realization was $58.16 per barrel, which reflects a premium of $1.71 per barrel versus West Texas Intermediate.

Continued to deliver outstanding results with the drilling program. In DeWitt County, our Buchhorn 4H-6H wells, which delivered average initial production rates of 2,475 BOE per day, are performing extremely well in spite of a variety of temporary constraints. In Brazos County, the Smith Family Ranch well has delivered initial production rate of nearly 1,258 BOE per day.Drilled and completed five new wells.

Continued to lower our operating expenses on a per-BOE basis. Compared to the ~~second~~first quarter of 2019, lease operating and gas gathering, and production and ad valorem taxes decreased on a per-BOE basis due to the continued increase in production throughout the year and our focus on controlling costs. General and administrative expense and interest expense also continue to decrease on a per-BOE basis.

Changes in operating results between the ~~third~~first quarters of ~~2019~~2020 and ~~2018~~2019 were primarily driven by the following:

Revenues decreased by ~~$5.6~~$3.7 million, or ~~10%~~9%, between the two quarters, primarily driven by a ~~55%~~38% decrease in commodity prices ~~largely~~partially offset by a ~~45%~~28% increase in production.

Our first quarter 2020 net loss includes a $199.9 million impairment charge on oil and gas properties, while our first quarter 2019 net loss includes a $33.5 million loss on sale of oil and gas properties.

Compared to the ~~third~~first quarter of ~~2018,~~2019, lease operating and gas gathering expense ~~increased $0.21,~~decreased $0.08, or 4%1%, per BOE, production and ad valorem taxes decreased ~~$0.99,~~$0.44, or ~~35%~~20%, per BOE, general and administrative expense decreased ~~$1.58,~~$2.12, or ~~39%~~50%, per BOE, and interest expense decreased ~~$2.12,~~$1.57, or ~~24%~~15%, per BOE.

Derivative financial instruments had a net gain of ~~$21.5~~$101.2 million in the ~~third~~first quarter of ~~2019,~~2020, compared to a net loss of ~~$18.2~~$36.2 million in the ~~third~~first quarter of ~~2018, due to an increase in the fair value adjustments between the periods of $30.4 million, and an increase in net derivative receipts of $9.3 million between the two periods.~~2019.

During the ~~third~~first quarter of ~~2019,~~2020, we recognized net ~~income~~loss attributable to common stockholders of ~~$14.1~~$113.0 million, or ~~$0.33~~$4.52 per diluted common share, compared to a net loss attributable to common stockholders of ~~$21.7~~$60.6 million, or ~~$0.88~~$2.45 per diluted common share, in the ~~third~~first quarter of ~~2018.~~

2019. We generated ~~$14.7~~$13.8 million of cash flow from operating activities during the ~~third~~first quarter of ~~2019,~~2020, which was ~~$2.9~~$4.0 million ~~less~~more than the ~~$17.6~~$9.8 million generated by operating activities during the ~~third~~first quarter of ~~2018.~~2019.

Gonzales County AMI

In February 2020, we entered into a Joint Development Agreement (the "JDA") in Gonzales County with one of the largest producers in the Eagle Ford which encompass an Area of Mutual Interest (the "AMI") totaling approximately 15,000 acres.

In June, we began flowback operations on the Hawkeye #14H, Hawkeye #15H, and Hawkeye #16H. These wells were the first wells completed in the AMI, and were drilled to total measured depths of 21,221, 20,924, and 20,228 feet, respectively. Our JDA partner did not participate in these wells, and on June 29, 2020 we completed a sale of 40% of the working interest in these wells to a third party for $9.1 million. The Hawkeye #14H, #15H, and #16H wells were fracture-stimulated in engineered completions using diverters with an average proppant concentration of 1,827 pounds per foot over 37, 36 and 34 stages, respectively. After the sale noted above, Lonestar has a 50% WI / 37.5% NRI in these wells.

~~Pirate Divestiture~~

~~On March 22, 2019, we completed~~Although these wells are in the ~~divestiture~~early stages of ~~our Pirate assets in Wilson County~~flowback, they are looking promising. Initial rates recorded for ~~$12.3 million, before closing adjustments, to a private third-party. The assets were comprised of 3,400 net undeveloped acres, six producing~~the wells held seven proved undeveloped locations as of the closing date, and were producing approximately 200 BOE per day. We recognized a loss of $32.9 million during the first quarter of 2019 in conjunction with the sale of the assets.are:

Hawkeye #14H - With a perforated interval of 10,979 feet, the #14H tested 1,419 Bbls/d oil, 108 Bbls/d of NGLs, 774 Mcf/d, or 1,656 BOE/d (three-stream) on a 30/64” choke.

Hawkeye #15H - With a perforated interval of 10,608 feet, the #15H tested 1,598 Bbls/d oil, 118 Bbls/d of NGLs, 849 Mcf/d, or 1,858 BOE/d (three-stream) on a 30/64” choke.

Hawkeye #16H - With a perforated interval of 9,885 feet, the #16H tested 1,483 Bbls/d oil, 111 Bbls/d of NGLs, 799 Mcf/d, or 1,727 BOE/d (three-stream) on a 30/64” choke.

RESULTS OF OPERATIONS

Certain of our operating results and statistics for the three ~~and nine~~ months ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ are summarized below:


In thousands, except per share and unit data	Three Months Ended September 30,					Nine Months Ended September 30,						Three Months Ended March 31,
In thousands, except per share and unit data	2019		2018			2019			2018			2020			2019
Operating Results
Net income (loss) attributable to common stockholders	$	14,058	$	(21,685	)	$	(35,394	)	$	(63,636	)
Net income (loss) per common share – basic⁽¹⁾	0.34		(0.88		)	(1.42		)	(2.59		)
Net income (loss) per common share – diluted⁽¹⁾	0.33		(0.88		)	(1.42		)	(2.59		)
Net loss attributable to common stockholders												$	(113,048	)	$	(60,629	)
Net loss per common share – basic⁽¹⁾												(4.52		)	(2.45		)
Net loss per common share – diluted⁽¹⁾												(4.52		)	(2.45		)
Net cash provided by operating activities	14,686		17,069			52,873			55,820			13,835			9,826
Revenues
Oil	$	42,187	$	47,846		$	120,496		$	120,705		$	29,990		$	33,584
NGLs	3,439		6,795			10,381			12,939			2,599			3,393
Natural gas	7,519		4,096			15,224			9,637			4,420			3,764
Total revenues	$	53,145	$	58,737		$	146,101		$	143,281		$	37,009		$	40,741
Total production volumes by product
Oil (Bbls)	725,405		660,836			2,024,862			1,758,393			658,476			590,096
NGLs (Bbls)	387,256		262,660			868,811			571,389			303,485			217,561
Natural gas (Mcf)	3,313,757		1,343,016			6,210,617			3,190,824			2,110,381			1,295,204
Total barrels of oil equivalent (6:1)	1,664,954		1,147,332			3,928,776			2,861,586			1,313,691			1,023,524
Daily production volumes by product
Oil (Bbls/d)	7,885		7,183			7,417			6,441			7,236			6,557
NGLs (Bbls/d)	4,209		2,855			3,182			2,093			3,335			2,417
Natural gas (Mcf/d)	36,019		14,600			22,750			11,689			23,191			14,391
Total barrels of oil equivalent (BOE/d)	18,097		12,471			14,391			10,482			14,436			11,372
Average realized prices
Oil ($ per Bbl)	$	58.16	$	72.40		$	59.51		$	68.65		$	45.54		$	56.90
NGLs ($ per Bbl)	8.88		25.87			11.95			22.64			8.56			15.60
Natural gas ($ per Mcf)	2.27		3.05			2.45			3.02			2.09			2.91
Total oil equivalent, excluding the effect from commodity derivatives ($ per BOE)	31.92		51.19			37.19			50.07			28.17			39.80
Total oil equivalent, including the effect from commodity derivatives ($ per BOE)	31.59		43.97			35.78			43.62			34.40			39.09
Operating and other expenses
Lease operating and gas gathering	$	10,055	$	6,687		$	26,695		$	17,761		$	9,788		$	7,710
Production and ad valorem taxes	3,017		3,218			8,126			8,145			2,369			2,291
Depreciation, depletion and amortization	24,635		23,775			64,120			59,937			24,354			17,970
General and administrative	4,124		4,661			12,345			13,385			2,881			4,379
Interest expense	11,295		10,215			32,730			28,771			11,610			10,656
Operating and other expenses per BOE
Lease operating and gas gathering	$	6.04	$	5.83		$	6.79		$	6.21		$	7.45		$	7.53
Production and ad valorem taxes	1.81		2.80			2.07			2.85			1.80			2.24
Depreciation, depletion and amortization	14.80		20.72			16.32			20.95			18.54			17.56
General and administrative	2.48		4.06			3.14			4.68			2.19			4.28
Interest expense	6.78		8.90			8.33			10.05			8.84			10.41

(1) Basic and diluted earnings per share are calculated using the two-class method. See Footnote 1. Basis of Presentation in the Notes to Unaudited Condensed Consolidated Financial Statements included in Item 1.

Production

The table below summarizes our production volumes for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2019	2018	Change		2019	2018	Change		2020	2019	Change
Oil (Bbls/d)	7,885	7,183	10	%	7,417	6,441	15	%	7,236	6,557	10	%
NGLs (Bbls/d)	4,209	2,855	47	%	3,182	2,093	52	%	3,335	2,417	38	%
Natural gas (Mcf/d)	36,019	14,600	147	%	22,750	11,689	95	%	23,191	14,391	61	%
Total (BOE/d)	18,097	12,471	45	%	14,391	10,482	37	%	14,436	11,372	27	%

Total production during the ~~third~~first quarter of ~~2019~~2020 averaged ~~18,097~~14,436 BOE per day, an increase of ~~45%~~27%, or ~~5,626~~3,064 BOE per day, compared to the same period in ~~2018. Total production during the first nine months of 2019 averaged 14,391 BOE per day, an increase of 37%, or 3,909 BOE per day, compared to the same period in 2018.~~2019. This increase was primarily driven by development of our Eagle Ford acreage, partially offset by approximately 200 BOE per day lost with ~~a much smaller increase attributable to incremental production from producing wells acquired~~the Pirate divestiture which occurred in ~~November 2018 in the Sooner acquisition.~~March 2019.

Our production during the ~~third~~first quarter of ~~2019~~2020 was ~~67%~~73% oil and NGLs, compared to ~~80%~~79% during the ~~third~~first quarter of ~~2018.~~2019.

Oil, Natural Gas Liquid and Natural Gas Revenues

The table below summarizes our production revenues for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:


In thousands	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
In thousands	2019		2018		Change		2019		2018		Change		2020		2019		Change
Oil	$	42,187	$	47,846	(12	)%	$	120,496	$	120,705	—	%	$	29,990	$	33,584	(11	)%
NGLs	3,439		6,795		(49	)%	10,381		12,939		(20	)%	2,599		3,393		(23	)%
Natural gas	7,519		4,096		84	%	15,224		9,637		58	%	4,420		3,764		17	%
Total revenues	$	53,145	$	58,737	(10	)%	$	146,101	$	143,281	2	%	$	37,009	$	40,741	(9	)%

Our oil, NGL and natural gas revenues during the three months ended ~~September 30, 2019~~March 31, 2020 decreased ~~$5.6~~$3.7 million, or ~~10%~~9%, compared to those revenues for the same period in ~~2018. For the nine months ended September 30, 2019, our oil, NGL and natural gas revenues increased $2.8 million, or 2%, compared to these revenues for the same period in 2018.~~2019. The changes in our oil, NGL and natural gas revenues are due to changes in production quantities and commodity prices (excluding any impact of our commodity derivative contracts), as reflected in the following table:


In thousands	Three Months Ended September 30, 2019 vs 2018					Nine Months Ended September 30, 2019 vs 2018					Three Months Ended March 31, 2020 vs 2019
	Three Months Ended September 30, 2019 vs 2018					Nine Months Ended September 30, 2019 vs 2018					Three Months Ended March 31, 2020 vs 2019
	Increase (Decrease) in Revenues			Percentage Increase (Decrease) in Revenues		Increase (Decrease) in Revenues			Percentage Increase (Decrease) in Revenues		Increase (Decrease) in Revenues			Percentage Increase (Decrease) in Revenues
Change in oil, NGL and natural gas revenues due to:
Increase in production	$	26,497		45	%	$	53,435		37	%	$	11,549		28	%
Decrease in commodity prices	(32,089		)	(55	)%	(50,615		)	(35	)%	(15,281		)	(39	)%
Total change in oil, NGL and natural gas revenues	$	(5,592	)	(10	)%	$	2,820		2	%	$	(3,732	)	(9	)%

Excluding the impact of our commodity derivative contracts, our net realized commodity prices and NYMEX differentials were as follows during the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:


	Three Months Ended September 30,							Nine Months Ended September 30,							Three Months Ended March 31,
	2019			2018		Change		2019			2018		Change		2020			2019			Change
Average net realized price
Oil ($/Bbl)	$	58.16		$	0.07	(20	)%	$	59.51		$	68.65	(13	)%	$	45.54		$	56.90		(20	)%
NGLs ($/Bbls)	8.88			0.03		(66	)%	11.95			22.64		(47	)%	8.56			15.60			(45	)%
Natural gas ($/Mcf)	2.27			3.05		(26	)%	2.45			3.02		(19	)%	2.09			2.91			(28	)%
Total ($/BOE)	31.92			51.19		(38	)%	37.19			50.07		(26	)%	28.17			39.80			(29	)%
Average NYMEX differentials
Oil per Bbl	$	1.71		$	2.90	(41	)%	$	2.69		$	1.88	43	%	$	0.03		$	2.00		(99	)%
Natural gas per Mcf	(0.11		)	0.15		(173	)%	(0.16		)	0.08		(300	)%	(0.18		)	(0.01		)	1,744	%

The average wellhead price for our production in the three months ended ~~September 30, 2019~~March 31, 2020 was ~~$31.92~~$28.17 per BOE, a ~~38%~~29% decrease compared to the average price for the comparable period in ~~2018. The realized wellhead price for the nine months ended September 30, 2019 was $37.19 per BOE, a 26% decrease compared to the average price for the comparable period in 2018.~~2019. Reported wellhead realizations were driven lower by a decrease in the crude oil and natural gas benchmark prices between the periods, in addition to a significantly lower NYMEX oil differential.

Our realized NGL price of ~~$8.88~~$8.56 per Bbl, or ~~16%~~19% of NYMEX WTI, was largely due to a sharp drop in ethane prices, which have fallen approximately 70% from the first quarter of 2019, and the pricing received for propane and other heavy liquids, which have fallen approximately 44% from the first quarter of 2019.prices.

Our average NYMEX oil differential decreased quarter over quarter by ~~$1.19~~$1.97 per Bbl, largely due to the decreased spread between Louisiana Light Sweet ("LLS") prices, for which substantially all of our crude oil sales were based for the periods presented, and NYMEX WTI benchmark prices.

Our natural gas NYMEX differentials are generally caused by movement in the NYMEX natural gas prices during the month, as most of our natural gas is sold on an index price that is set near the first of each month. While the percentage change in NYMEX natural gas differentials can be large, these differentials are seldom more than a dollar above or below NYMEX price.

Commodity Derivative Contracts

We utilize oil and natural gas derivative contracts to provide an economic hedge of our exposure to commodity price risk associated with anticipated future production and to provide more certainty to our future cash flows. These contracts have historically consisted of fixed-price swaps, collars and basis swaps.

The following table summarizes the net cash (payments) receipts on the Company's commodity derivatives and the relative price impact (per Bbl or Mcf) for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018~~2019:


	Three Months Ended September 30,												Nine Months Ended September 30,												Three Months Ended March 31,
	2019						2018						2019						2018						2020						2019
In thousands, except price impact	Net realized settlements			Price impact			Net realized settlements			Price impact			Net realized settlements			Price impact			Net realized settlements			Price impact			Net realized settlements			Price impact			Net realized settlements		Price impact
Payments on settlements of oil derivatives	$	(1,022	)	$	(1.41	)	$	(7,190	)	$	(10.88	)	$	(5,627	)	$	(2.78	)	$	(16,070	)	$	(9.13	)
Receipts (payments) on settlements of natural gas derivatives	178			0.05			(437		)	(0.33		)	1,769			0.28			(253		)	(0.08		)
(Payments) receipts on settlements of oil derivatives																									$	(155	)	$	(0.24	)	$	462	$	0.78
Receipts on settlements of natural gas derivatives																									1,236			0.59			847		0.65
Total net commodity derivative settlements	$	(844	)				$	(7,627	)				$	(3,858	)				$	(16,323	)				$	1,081					$	1,309

Our realized net ~~loss~~gain on commodity derivative contracts was ~~$0.6 million and $5.5~~$8.2 million for the three ~~and nine~~ months ended ~~September 30, 2019, respectively.~~March 31, 2020, as compared to net loss of $0.7 million for the three months ended March 31, 2019. We realized an average ~~loss~~gain of ~~$0.33 and $1.41~~$6.23 per BOE on our oil and natural gas swaps during the three ~~and nine~~ months ended ~~September 30, 2019, respectively,~~March 31, 2020, as compared to an average loss of ~~$7.22 and $6.45~~$0.72 per BOE for the three ~~and nine~~ months ended ~~September 30, 2018, respectively.~~March 31, 2019.

Production Expenses

The table below presents detail of production expenses for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:


In thousands, except expense per BOE	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
In thousands, except expense per BOE	2019		2018		Change		2019		2018		Change		2020		2019		Change
Production expenses
Lease operating and gas gathering	$	10,055	$	6,687	50	%	$	26,695	$	17,761	50	%	$	9,788	$	7,710	27	%
Production and ad valorem taxes	3,017		3,218		(6	)%	8,126		8,145		—	%	2,369		2,291		3	%
Depreciation, depletion and amortization	24,635		23,775		4	%	64,120		59,937		7	%	24,354		17,970		36	%
Production expenses per BOE
Lease operating and gas gathering	$	6.04	$	5.83	4	%	$	6.79	$	6.21	9	%	$	7.45	$	7.53	(1	)%
Production and ad valorem taxes	1.81		2.80		(35	)%	2.07		2.85		(27	)%	1.80		2.24		(19	)%
Depreciation, depletion and amortization	14.80		20.72		(29	)%	16.32		20.95		(22	)%	18.54		17.56		6	%

Lease Operating and Gas Gathering

The table below provides detail of our lease operating and gas gathering expense for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:


In thousands	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
In thousands	2019		2018		Change		2019		2018		Change		2020		2019		Change
Lease operating	$	8,948	$	5,900	52	%	$	23,472	$	15,735	49	%	$	7,638	$	6,831	12	%
Gas gathering, processing and transportation	1,107		787		41	%	3,223		2,026		59	%	2,150		879		145	%
Total lease operating and gas gathering expense	$	10,055	$	6,687	50	%	$	26,695	$	17,761	50	%	$	9,788	$	7,710	27	%

Lease operating expenses are the costs incurred in the operation of producing properties and workover costs. Expenses for direct labor, water injection and disposal, utilities, materials and supplies comprise the most significant portion of our lease operating expenses. Lease operating expenses do not include general and administrative expenses or production and ad valorem taxes.

Our lease operating and gas gathering expense increased ~~$3.4~~$2.1 million, or ~~50%~~27%, for the three months ended ~~September 30, 2019~~March 31, 2020 to ~~$10.1~~$9.8 million from ~~$6.7~~$7.7 million in the comparable period ~~in 2018. On a nine-month comparative basis, these expenses increased $8.9 million, or 50%, from $17.8 million in 2018 to $26.7 million~~ in 2019. On a unit-of-production basis, lease operating and gas gathering expense ~~increased 4%~~decreased 1%, or ~~$0.21~~$0.08 per BOE, from ~~$5.83~~$7.53 per BOE in the three months ended ~~September 30, 2018~~March 31, 2019 to ~~$6.04~~$7.45 per BOE in the three months ended September 30, 2019. On a nine-month comparative basis, these expenses increased 9%, or $0.58 per BOE, from $6.21 per BOE in the nine months ended September 30, 2018 to $6.79 per BOE for the nine months ended September 30, 2019.March 31, 2020. The increase in total lease operating costs is due to continuing incremental production brought online by our Eagle Ford development program, as well as higher gas processing costs in the current year.

Compared to the ~~second~~fourth quarter of 2019, lease operating and gas gathering expense ~~increased 13%~~decreased 23%, or ~~$1.1~~$2.2 million. On a unit-of-production basis, these expenses ~~decreased 16%~~increased 22%, or ~~$1.16~~$1.33 per BOE, from the ~~second~~fourh quarter of 2019.

Production and Ad Valorem Taxes

Production taxes are paid on produced crude oil and natural gas based upon a percentage of gross revenues or at fixed rates established by state or local taxing authorities. In general, the production taxes we pay correlate to the changes in oil and natural gas revenues. We are also subject to ad valorem taxes in the counties where our production is located. Ad valorem taxes are generally based on the valuation of our oil and natural gas properties.

The following table provides detail of our production and ad valorem taxes for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~

2019:


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
In thousands	2019		2018		Change		2019		2018		Change		2020		2019		Change
Production taxes	$	1,860	$	2,888	(36	)%	$	5,958	$	6,920	(14	)%	$	1,325	$	1,786	(26	)%
Ad valorem taxes	1,157		330		251	%	2,168		1,225		77	%	1,044		505		107	%
Total production and ad valorem tax expense	$	3,017	$	3,218	(6	)%	$	8,126	$	8,145	—	%	$	2,369	$	2,291	3	%

Our total production and ad valorem tax expense ~~decreased 6%~~increased 3%, or ~~$0.2~~$0.1 million, between the three months ended ~~September 30, 2019~~March 31, 2020 and ~~2018. On a nine-month comparative basis, these expenses remained relatively flat at around $8.1million. For both periods presented, production~~2019. Production taxes were lower in the current period due to lower revenues, caused in-turn by lower commodity prices. Ad valorum taxes were higher in the current period due to higher reserve values for our properties. On a unit-of-production basis, production and ad valorem tax expense decreased ~~35%~~19%, or ~~$0.99~~$0.44 per BOE, from ~~$2.80~~$2.24 per BOE in the three months ended ~~September 30, 2018~~March 31, 2019 to ~~$1.81~~$1.80 per BOE in the three months ended September 30, 2019. On a nine-month comparative basis, these expenses decreased 27%, or $0.78 per BOE, from $2.85 per BOE for the nine months ended September 30, 2018, to $2.07 per BOE for the nine months ended September 30, 2019.March 31, 2020. This decrease in the per-BOE rate is attributable to lower commodity prices received for our production ~~due to lower realized commodity prices~~ in the current ~~periods.~~period.

Compared to the ~~second~~fourth quarter of 2019, production and ad valorem taxes ~~increased $0.2~~decreased $0.7 million, or 7%22%. This ~~increase~~decrease correlates with the ~~increase~~decrease in the Company's production between the periods ~~offset by~~in addition to lower commodity prices. On a unit-of-production basis, these expenses decreased ~~20%~~4%, or ~~$0.46~~$0.08 per BOE, from the ~~second~~fourth quarter of 2019.

Depreciation, Depletion and Amortization

The table below provides detail of our depreciation, depletion and amortization ("DD&A") expense for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018.~~2019.


In thousands	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
In thousands	2019		2018		Change		2019		2018		Change		2020		2019		Change
Depletion of proved oil and gas properties	$	24,178	$	23,552	3	%	$	62,813	$	59,112	6	%	$	23,905	$	17,556	36	%
Depreciation of other property and equipment	378		178		112	%	1,071		693		55	%	363		336		8	%
Accretion of asset retirement obligations	79		45		76	%	236		132		79	%	86		78		10	%
Total DD&A expense	$	24,635	$	23,775	4	%	$	64,120	$	59,937	7	%	$	24,354	$	17,970	36	%

Capitalized costs attributed to our proved properties are subject to depreciation and depletion calculated using the unit-of-production method. For leasehold acquisition costs and the cost to acquire proved properties, the reserve base used to calculate depreciation and depletion is the sum of proved developed reserves and proved undeveloped reserves. For well costs, the reserve base used to calculate depletion and depreciation is proved developed reserves only. Other property and equipment are carried at cost, and depreciation is calculated using the straight-line method over the estimated useful lives of the assets, ranging from three to five years.

DD&A expense for the three months ended ~~September 30, 2019~~March 31, 2020 was ~~$24.6~~$24.4 million, a 4%36% increase from ~~$23.8~~$18.0 million in the comparable period ~~in 2018. On a nine-month comparative basis, these expenses increased $4.2 million, or 7%, from $59.9 million in 2018 to $64.1 million~~ in 2019. This increase is due to continued development of our properties in the Eagle Ford. On a unit-of-production basis, DD&A ~~decreased 29%~~increased 6%, or ~~$5.92~~$0.98 per BOE, from ~~$20.72~~$17.56 per BOE for the three months ended ~~September 30, 2018~~March 31, 2019 to ~~$14.80~~$18.54 per BOE for the three months ended ~~September 30, 2019. This decrease reflects reserve growth from quarter to quarter due to the continuous development of our properties and, to a lesser extent, the Sooner acquisition in November 2018.~~March 31, 2020.

Compared to the ~~second~~fourth quarter of 2019, DD&A expense for the three months ended ~~September 30, 2019 increased $3.1 million, or 15%.~~March 31, 2020 decreased $0.1 million. On a unit-of-production basis, DD&A ~~decreased~~increased by ~~$2.55~~$2.96 per BOE, or ~~15%~~3%, from the ~~second~~fourth quarter of 2019.

Loss on Sale of Oil and Gas Properties

OnIn March, ~~22,~~ 2019, we completed the divestiture of ~~our~~its Pirate assets in Wilson County for ~~$12.3~~an adjusted cash purchase price of $11.5 million, ~~before~~after closing adjustments, to a private ~~third party.~~third-party. The assets were comprised of 3,400 net undeveloped acres, six producing wells, held seven proved undeveloped locations as of the closing date, and were producing approximately 200 ~~BOE per day.~~BOE/d. We recognized a loss of ~~$32.9~~$33.5 million during the first quarter of 2019 in conjunction with the sale of the assets.

Impairment of Oil and Gas Properties

We evaluate impairment of proved and unproved oil and gas properties on a region basis. On this basis, certain regions may be impaired because they are not expected to recover their entire carrying value from future net cash flows.

During the first quarter of 2020, we recorded impairment charges totaling approximately $199.9 million across various Eagle Ford properties, of which $199.0 million was proved and $0.9 million was unproved. These impairments resulted from removing PUDs and probable reserves from future development plans due to the continued depressed commodity prices and the uncertainly of Company's liquidity situation.

It is reasonably possible that the Company's estimate of undiscounted future net cash flows may change in the future resulting in the need to impair the carrying value of its properties. See Part II Item 1A. Risk Factors, for further discussion.

General and Administrative

General and administrative ("G&A") expense decreased ~~$0.6~~$1.5 million, or ~~12%~~33%, to ~~$4.1~~$2.9 million in the three months ended ~~September 30, 2019,~~March 31, 2020, from ~~$4.7~~$4.4 million for the comparable period in ~~2018.~~2019. This decrease reflects ~~lower professional feels and compensatoin~~gains in stock-based compensation in the current ~~quarter. On a nine-month comparative basis, G&A decreased $1.0 million, or 8%~~quarter (see below), ~~between the two periods.~~partially offset by higher compensation expense. On a unit-of-production basis, G&A expense decreased ~~39%~~49%, or ~~$1.58~~$2.09 per BOE, from ~~$4.06~~$4.28 per BOE in the three months ended ~~September 30, 2018~~March 31, 2019 to ~~$2.48~~$2.19 per BOE in the three months ended ~~September 30, 2019.~~March 31, 2020. This decrease was due to the increase in production volumes quarter to quarter, as well as the changes in total expense noted above.

Stock-based compensation gains included in G&A was $1.8 million for the three months ended March 31, 2020, versus expense of $0.9 million for the three months ended ~~September 30, 2019, versus $2.3 million~~March 31, 2019. These awards are accounted for ~~the three months ended September 30, 2018. This decrease was~~as liabilities and these liabilities decreased due to ~~changes~~the decrease in ~~valuations of~~ the ~~underlying awards.~~Company's stock price during the quarter, which in-turn caused a gain in G&A.

Compared to the ~~second~~fourth quarter of 2019, G&A expense for the three months ended ~~September 30, 2019 increased $0.3~~March 31, 2020 decreased $1.3 million, or 7%31%. On a unit-of-production basis, G&A expense decreased by ~~$0.62~~$0.38 per BOE, or ~~20%~~15%, from the ~~second~~fourth quarter of 2019.

Interest Expense

The table below provides detail of the interest expense for our various long-term obligations for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:


In thousands	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
In thousands	2019		2018		Change		2019		2018		Change		2020		2019		Change
Interest expense on 11.25% Senior Notes	$	7,032	$	7,031	—	%	$	21,094	$	20,859	1	%	$	7,031	$	7,031	—	%
Interest expense on Credit Facility	3,494		1,895		84	%	9,317		4,296		117	%	3,685		2,824		30	%
Other interest expense	136		253		(46	)%	368		497		(26	)%	126		100		26	%
Total cash interest expense ⁽¹⁾	$	10,662	$	9,179	16	%	$	30,779	$	25,652	20	%	$	10,842	$	9,955	9	%
Amortization of debt issuance costs and discounts	633		1,036		(39	)%	1,950		3,119		(37	)%	768		701		10	%
Total interest expense	$	11,295	$	10,215	11	%	$	32,729	$	28,771	14	%	$	11,610	$	10,656	9	%
Per BOE:
Total cash interest expense	$	6.40	$	8.00	(20	)%	$	7.83	$	8.96	(13	)%	$	8.25	$	9.73	(15	)%
Total interest expense	6.78		8.90		(24	)%	8.33		10.05		(17	)%	8.84		10.41		(15	)%

(1) Cash interest is presented on an accrual basis.

Our total interest expense in the three months ended ~~September 30, 2019~~March 31, 2020 was ~~$11.3~~$11.6 million, an ~~11%~~9% increase from ~~$10.2~~$10.7 million in the comparable period in ~~2018. On a nine-month comparative basis, total interest expense increased $3.9 million, or 14%, from $28.8 million in 2018 to $32.7 million in~~ 2019. ~~These increases are~~This increase is primarily due to a combination of a higher principal ~~and floating rates~~balance on our Credit Line (as defined below) in ~~2019, partially offset by lower non-cash interest expense.~~the current quarter.

On a unit-of-production basis, total interest expense decreased by ~~24%~~15%, or ~~$2.12~~$1.57 per BOE, from ~~$8.90~~$10.41 per BOE in the three months ended ~~September 30, 2018~~March 31, 2019 to ~~$6.78~~$8.84 per BOE in the three months ended ~~September 30, 2019. On a nine-month comparative basis, total interest expense decreased 17%, or $1.72 per BOE, from $10.05 per BOE in 2018 to $8.33 per BOE in 2019.~~March 31, 2020.

Compared to the ~~second~~fourth quarter of 2019, interest expense for the three months ended ~~September 30, 2019~~March 31, 2020 slightly increased by $0.5 million, primarily due to higher borrowing on our Credit Facility. On a unit-of-production basis, interest expense ~~decreased 22%~~increased 28%, or ~~$1.91~~$1.93 per BOE, from the ~~second~~fourth quarter of 2019.

Income Taxes

The following table provides further detail of our income taxes for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:

In thousands, except per-BOE amounts and tax rates Three Months Ended September 30, Nine Months Ended September 30,
2019 2018 2019 2018
Current income tax benefit (expense) $ (18 ) $ (432 ) $ 26
$ (652 )
Deferred income tax (expense) benefit (4,749 ) 714
6,940
7,145
Total income tax (expense) benefit $ (4,767 ) $ 282
$ 6,966
$ 6,493
Average income tax (expense) benefit per BOE $ (2.86 ) $ 0.25
$ 1.77
$ 2.27
Effective tax rate 22.7 % 1.4 % 19.3 % 10.1 %
Total net deferred tax liability on balance sheet at period end $ 5,387
$ 2,380



In thousands, except per-BOE amounts and tax rates	Three Months Ended March 31,
In thousands, except per-BOE amounts and tax rates	2020			2019
Current income tax benefit	$	424		$	11
Deferred income tax benefit	931			12,922
Total income tax benefit	$	1,355		$	12,933
Average income tax benefit per BOE	$	1.03		$	12.64
Effective tax rate	1.2		%	18.1		%
Total net deferred tax asset (liability) on balance sheet at period end	$	—		$	552

~~Income~~As a result of the loss before income tax of $112.1 million in the three months ended March 31, 2020 and net loss before income tax of $71.5 million in the three months ended March 31, 2019, we recorded income tax benefit of $1.4 million and $12.9 million in the three months ended March 31, 2020 and 2019, respectively.

On March 27, 2020, Congress enacted the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) to provide certain taxpayer relief as a result of the COVID-19 pandemic. The CARES Act included several favorable provisions that impacted income taxes, primarily the modified rules on the deductibility of business interest expense ~~increased $5.0 million between~~for 2019 and 2020, a five-year carryback period for net operating losses generated after 2017 and before 2021, and the ~~comparable quarters primarily due to net income for the current quarter. Year to date,~~acceleration of refundable alternative minimum tax credits. The CARES Act did not materially impact our effective tax rate for the three months ended March 31, 2020, and we are currently assessing the potential future impact.

Our deferred tax assets exceeded our deferred tax liabilities at March 31, 2020 primarily due to tax consequences of the impairment of our proved properties during the first quarter of 2020; as a result, we retained a full valuation allowance of $32.6 million at March 31, 2020 due to uncertainties regarding the future realization of our deferred tax assets. The valuation allowance is ~~slightly less than~~also the ~~effective~~primary cause for the variance between our statutory tax rate of 21% ~~due~~and the effective tax rate of 1.2% for the quarter. The valuation allowance will continue to ~~return-to-provision state~~be recognized until the realization of future deferred tax ~~deferral adjustments.~~benefits is determined to be more likely than not.

CAPITAL RESOURCES AND LIQUIDITY

Liquidity and Capital Resources

We expect that our primary source of liquidity will be cash flows generated by operating ~~activities, borrowings under our $500,000,000 Senior Secured Credit Facility (the "Credit Facility") and, if warranted, equity offerings.~~activities. During the first ~~nine months~~quarter of ~~2019,~~2020, we generated cash flows from operations of ~~$52.9~~$13.8 million, after giving effect to ~~a $12.5~~$3.3 million ~~change~~of positive changes in cash ~~inflows~~flows from working capital. As of July 2, 2020, our Credit Facility had an outstanding balance of $285 million and a borrowing-base deficiency of $60.4 million as a result of the terms of the Forbearance Agreement (see below), which will need to be repaid within 60 days of July 2, 2020. We did not make a $14.1 million interest payment on our 11.25% Senior Notes due July 1, 2020.

~~Our~~

The Company's primary needs for cash are for capital expenditures, acquisitions of oil and natural gas properties, payments of contractual obligations and working capital obligations. We have historically financed our business through cash flows from operations, borrowings under our Credit Facility and the issuance of bonds and equity offerings. As circumstances warrant, we may access the capital markets and issue equity or debt from time to time on an opportunistic basis in a continued effort to optimize our balance sheet and to fund our operations and capital expenditures in the future, dependent upon market conditions and available ~~pricing. Such uses~~pricing, however this is unlikely with our current financial condition. Uses of such proceeds may include repayment of our debt, development or acquisition of additional acreage or proved properties, ~~pay cash dividends on the Series A-1 Preferred Stock~~ and general corporate purposes. There can be no assurance that future funding of transactions will be available on favorable terms, or at all, and we therefore cannot guarantee the outcome of any such transactions.

As discussed above, NYMEX oil prices have decreased significantly since the beginning of 2020, decreasing from nearly $60 per barrel in early January to the upper $30s per barrel in late June and were considerably lower during the months of April and May. This decrease in the market prices for our production directly reduce our operating cash flow and indirectly impact our other sources of potential liquidity, such as lowering our borrowing capacity under our revolving credit facility, as our borrowing capacity and borrowing costs are generally related to the estimated value of our proved reserves. In this low oil price environment, we have taken various steps to preserve our liquidity including (1) by reducing our 2020 budgeted development capital spending, (2) by continuing to focus on reducing our operating and overhead costs, and (3) by adding additional commodity hedges for 2021 to reduce our long-term exposure to commodity prices.

At ~~September 30, 2019,~~March 31, 2020, we had ~~$3.4~~$1.1 million in cash and cash equivalents and ~~$44.6~~approximately $22.6 million of ~~additional~~ availability under our Credit Facility. As of July 2, 2020 the borrowing base was redetermined to $225 million from $286 million pursuant to the Forbearance Agreement. The outstanding balance under our credit facility was $285 million as of July 2, 2020, which represents a borrowing deficiency of $60.4 million, and we are obligated to pay the deficiency within 60 days after July 2, 2020.

We ~~believe~~did not satisfy the consolidated current ratio covenant under the Credit Facility as of the March 31, 2020 measurement date and did not make an interest payment date under the 11.25% Senior Notes that ~~our existing cash and cash equivalents, cash expected to be generated from operations~~was due on July 1, 2020. Such failures currently represent events of default under the Credit Facility, and the ~~availability~~missed interest payment will also represent an event of ~~borrowing~~default under the 11.25% Senior Notes if not cured within 30 days. The Company received a forbearance from the lenders under the Credit Facility until July 31, 2020 for the default in the consolidated current ratio covenant as of the March 31, 2020 measurement date and the missed interest payment pursuant to the Forbearance Agreement. Despite the forbearance, the defaults under the Credit Facility are continuing, and will continue, absent a waiver from the lenders. We do not anticipate maintaining compliance with the consolidated current ratio over the next twelve months.

We do not anticipate maintaining compliance with the consolidated current ratio covenant under our Credit Facility over the next twelve months, and are evaluating the available financial alternatives, including obtaining acceptable alternative financing as well as seeking additional waivers, forbearances or amendments to the covenants or other provisions of the Credit Facility to address any existing or future defaults and have engaged financial and legal advisors to assist the Company. If we are unable to reach an agreement with its lenders or find acceptable alternative financing, the lenders of the Credit Facility may choose to accelerate repayment, in addition to the $60.4 million due from the current borrowing base deficiency noted above, which in turn may result in an event of default and an acceleration of the 11.25% Senior Notes. If our lenders or our noteholders accelerate the payment of amounts outstanding under our Credit Facility or the 11.25% Senior Notes, respectively, the Company does not currently have sufficient liquidity to repay such indebtedness and would need additional sources of capital to do so. While we believe the proceeds of assets sales can fund immediate working capital needs, in the context of the current market conditions it is unclear whether we can obtain any additional sources of capital.

We cannot provide any assurances that we will be successful in any restructuring of existing debt obligations or obtaining capital sufficient to fund the refinancing of its outstanding indebtedness or to provide sufficient liquidity to meet our ~~liquidity requirements, anticipated capital expenditures~~operating needs. If the Company is unsuccessful in its efforts to restructure and ~~payments due~~obtain new financing, it may be necessary for us to seek protection from creditors under Chapter 11 of the U.S. Bankruptcy Code (“Chapter 11”), or an involuntary petition for bankruptcy may be filed against us. We have concluded that these circumstances create substantial doubt regarding our ~~existing credit facility and notes outstanding for at least the next 12 months.~~ability to continue as a going concern.

~~The cash~~Cash flows for the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ are presented below:


In thousands	Nine Months Ended September 30,						Three Months Ended March 31,
In thousands	2019			2018			2020			2019
Net cash provided by (used in):
Operating activities	$	52,873		$	55,820		$	13,835		$	9,826
Investing activities	(116,569		)	(129,084		)	(35,776		)	(22,298		)
Financing activities	61,782			75,268			19,946			10,884
Net change in cash	$	(1,914	)	$	2,004		$	(1,995	)	$	(1,588	)

Net Cash Provided by Operating Activities

Net cash provided by operating activities of ~~$52.9~~$13.8 million for the first ~~nine~~three months of 2020 was $4.0 million more than the first three months of 2019, ~~was $2.9 million less than the first nine months of 2018,~~ which totaled ~~$55.8~~$9.8 million. Excluding changes in operating assets and liabilities, net cash provided by operating activities ~~increased $9.9~~decreased $7.8 million. Compared to the first ~~nine~~three months of ~~2018,~~2019, the first ~~nine~~three months of ~~2019~~2020 had significantly lower commodity prices which were largely offset by higher oil and natural gas production. Changes in our operating assets and liabilities between the ~~nine~~three months ended ~~September 30, 2018~~March 31, 2019 and the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 resulted in a net ~~decrease~~increase of approximately ~~$12.9~~$11.8 million in net cash provided by operating activities for the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, as compared to the ~~nine~~three months ended ~~September 30, 2018.~~March 31, 2019.

Net Cash Used in Investing Activities

Net cash used in investing activities ~~decreased $12.5~~increased $13.5 million, from ~~$129.1~~$22.3 million in the ~~nine~~three months ended ~~September 30, 2018~~March 31, 2019 to ~~$116.6~~$35.8 million in the ~~nine~~three months ended ~~September 30, 2019.~~March 31, 2020. This ~~decrease~~increase is primarily due to $12.0 million in proceeds from the sale of the Pirate assets in March 2019.

Net Cash Provided by Financing Activities

Net cash provided by financing activities ~~decreased $13.5~~increased $9.1 million, from ~~$75.3~~$10.9 million provided during the ~~nine~~three months ended ~~September 30, 2018~~March 31, 2019 to ~~$61.8~~$19.9 million provided in the ~~nine~~three months ended ~~September 30, 2019.~~March 31, 2020. This ~~decrease~~increase is primarily due to ~~higher net proceeds received during~~lower repayments of our Credit Line borrowing in the ~~first quarter of 2018 between the retirement of the 8.75% Senior Notes and the issuance of the 11.25% Senior Notes (see below).~~current quarter.

Debt

As of September 30, 2019, we had an aggregate of $499.8 million of indebtedness, including $245.0 million drawn on our Credit Facility, $250.0 million (less an unamortized discount of $3.7 million and debt issuance costs of $0.8 million) on our 11.25% Senior Notes and $9.2 million of other long-term notes.

Senior Secured Credit Facility

In July 2015, through our subsidiary, Lonestar Resources America, Inc. ("LRAI"), we entered into a $500 million Senior Secured Credit Facility with Citibank, N.A., as administrative agent, and other lenders party thereto (as amended, supplemented or modified from time to ~~time)~~time, the “Credit Facility”), which has a maturity date of ~~July 29, 2020.~~November 15, 2023. As of ~~September 30, 2019, $245.0~~March 31, 2020, $267.0 million was borrowed under the Credit Facility, and the weighted average interest rate on borrowings under the Credit Facility for the quarter was ~~5.32%~~5.30%. Borrowing availability was $22.6 million as of March 31, 2020, which reflects $0.4 million of letters of credit outstanding.

~~In June 2019,~~base under the ~~Company entered into the Borrowing Base Redetermination and Tenth Amendment to~~ Credit ~~Agreement (the "Tenth Amendment"), which (i) increased~~Facility. As of March 31, 2020, the borrowing base ~~from $275 million to $290 million~~ and ~~(ii) amended certain other provisions of~~lender commitments for the Credit Facility was $290 million. The borrowing base was lowered to $286 million on June 11, 2020 as ~~set forth more specifically~~part of the Thirteenth Amendment, and on July 2, 2020, the borrowing base was redetermined to $225 million from $286 million pursuant to the Forbearance Agreement. The outstanding balance under our credit facility was $285 million as of July 2, 2020 which represents a borrowing deficiency of $60.4 million. We are obligated to pay the deficiency within 60 days after July 2, 2020.

Borrowings under the Credit Facility, at our election, bear interest at either: (i) an alternate base rate (“ABR”) equal to the higher of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus 0.5% per annum, and (c) the adjusted LIBO rate of a three-month interest period on such day plus 1.0%; or (ii) the adjusted LIBO rate, which is the rate stated on Reuters screen LIBOR1 page, for one, two, three, six or twelve months, as adjusted for statutory reserve requirements for Eurocurrency liabilities, plus, in each of the cases described in clauses (i) and (ii) above, an applicable margin ranging from 1.0% to 2.0% (2.0% to 3.5% following the Thirteenth Amendment) for ABR loans and from 2.0% to 3.0% (3.0% to 4.5% following the Thirteenth Amendment) for adjusted LIBO rate loans.

As the Credit Facility is in a state of of default, 2.0% incremental default interest would typically be due but is currently not being charged as part of the terms of the Forbearance Agreement (see below).

Subject to certain permitted liens, our obligations under the Credit Facility are required to be secured by the grant of a first priority lien on no less than 80% of the value of the proved oil and gas properties of the Company and its subsidiaries (currently 100% following the Thirteenth Amendment).

The Credit Facility contains certain financial performance covenants, as defined in the ~~Tenth Amendment.~~Credit Facility, including the following:

A maximum debt to EBITDAX ratio of 4.0 to 1.0, and

A current ratio of not less than 1.0 to 1.0.

We were not in compliance with the terms of the Credit Facility as of ~~September 30, 2019.~~

~~Issuance~~December 31, 2019 because we did not satisfy the consolidated current ratio at those times and the audit report prepared by our auditors with respect to the financial statements in the 2019 Form 10-K included an explanatory paragraph expressing uncertainty as to our ability to continue as a "going concern." The lenders waived the current ratio default with respect to December 31, 2019, pursuant to the Waiver. The Company received a forbearance until July 31, 2020 for the default in the consolidated current ratio covenant as of the March 31, 2020 measurement date and the missed July 1, 2020 interest payment under the 11.25% Senior Notes pursuant to the Forbearance Agreement. Despite the forbearance, the defaults under the Credit Facility are continuing, and will continue, absent a waiver from the lenders. As we do not anticipate maintaining compliance with the consolidated current ratio covenant under our Credit Facility over the next twelve months, we are evaluating the available financial alternatives, including obtaining acceptable alternative financing as well as seeking waivers, forbearances or amendments to the covenants or other provisions of our revolving credit facility to address future defaults. We were not in compliance with the terms of the Credit Facility as of May 15, 2020, because we did not timely deliver our financial statements with respect to the fiscal quarter ended March 31, 2020. Such failure represented a default under the Credit Facility which the lenders waived pursuant to the Thirteenth Amendment. As noted above, the borrowing base was redetermined to $225 million from $286 million pursuant to the Forbearance Agreement. The outstanding balance under our credit facility was $285 million as of July 2, 2020 which represents a borrowing deficiency of $60.4 million. We are obligated to pay the deficiency within 60 days after July 2, 2020.

Waiver and Eleventh Amendment

Effective April 7, 2020, we entered into the Waiver and Eleventh Amendment (the "Waiver") to waive events of default arising from our failure to comply with the consolidated current ratio as of December 31, 2019, to timely provide audited financial statements and to provide financial statements that are not subject to any “going concern” or like qualification or exception for the fiscal year ended December 31, 2019. As there was no guarantee that our lenders will agree to waive events of default or potential events of default in the future, the amounts outstanding under the Credit Facility as of December 31, 2019 were classified as current in the accompanying 2019 Condensed Consolidated Balance Sheet.

Twelfth Amendment

Effective May 8, 2020, we entered into the Twelfth Amendment to Credit Agreement (the “ Twelfth Amendment”), to allow the Company to accept proceeds of up to $2.2 million from an unsecured loan applied for under the Coronavirus Aid, Relief and Economic Security Act.

We have applied for, and have received, funds under the Paycheck Protection Program after the period end in the amount of $2.2 million. The application for these funds requires us to, in good faith, certify that the current economic uncertainty made the loan request necessary to support the ongoing operations of the Company. This certification further requires us to take into account our current business activity and our ability to access other sources of liquidity sufficient to support ongoing operations in a manner that is not significantly detrimental to the business. The receipt of these funds, and the forgiveness of the loan attendant to these funds, is dependent on the Company having initially qualified for the loan and qualifying for the forgiveness of such loan based on our future adherence to the forgiveness criteria.

Waiver and Thirteenth Amendment

Effective June 11, 2020, we entered into the Waiver and Thirteenth Amendment to Credit Agreement (the "Thirteenth Amendment") which (i) waived any default or event of default arising from our failure to provide timely quarterly financial statements for the three months ended March 31, 2020; (ii) redetermined the borrowing base to $286 million from $290 million; (iii) set the next borrowing base redetermination to be on July 1, 2020 (and in any event, no later than July 31, 2020), (iv) amended the borrowing base utilization grid used in the applicable margin, as noted above and (v) until the July 1, 2020 redetermination, restricted the Company and its subsidiaries’ ability to incur debt with respect to, among other items, capital leases and permitted senior debt, grant liens to secure other obligations, pay dividends on LRAI’s preferred stock and make certain investments.

As there is no guarantee that our lenders will agree to waive events of default or potential events of default in the future, the amounts outstanding under the Credit Facility as of March 31, 2020 were classified as current in the accompanying Condensed Consolidated Balance Sheet.

Forbearance Agreement and Fourteenth Amendment

On July 2, 2020, we entered into a Forbearance Agreement, Fourteenth Amendment, and Borrowing Base Agreement with Citibank, N.A., as administrative agent and the lenders party thereto (the “Forbearance Agreement”) with respect to the Credit Facility. Pursuant to the Forbearance Agreement, among other things, (i) the lenders under the Credit Facility agree to refrain from exercising their rights and remedies under the Credit Facility and related loan documents with respect to certain defaults until July 31, 2020, (ii) the borrowing base was redetermined to $225 million from $286 million, (iii) all proceeds of dispositions and terminations or liquidations of swap agreements shall be used to repay the Credit Facility and shall automatically reduce the borrowing base by the amount of the repayment and (iv) certain exceptions to the covenant restriction on investments shall no longer be available.

The rights of the lenders to exercise rights and remedies resulted from our failure to comply with the current ratio with respect to the quarter ended March 31, 2020 and the defaults expected with respect to the quarter ending Jun 30, 2020, under the current ratio and the leverage ratio covenants, and the default with respect to the failure to make the interest payment due on July 1, 2020, under the 11.25% Senior Notes.

The Forbearance Agreement can be terminated by the lenders upon (i) the occurrence of any default or event of default under the Credit Facility other than those disclosed, (ii) the failure of the Company to comply with any of the terms and requirements of the Forbearance Agreement, (iii) the breach of any representation or warranty, (iv) the exercise of any rights by other debt holders relating to foreclosure or acceleration and (v) the commencement of any bankruptcy proceeding with respect to any loan party. Additionally, the Forbearance Agreement can be terminated if we fail to deliver a detailed restructuring proposal to the lenders by July 16, 2020. If the Forbearance Agreement terminates and any then-current and ongoing events of default have not been waived or cured, the lenders will be able to accelerate the loans and pursue their rights and remedies.

11.25% Senior Notes

In January 2018, wethe Company issued ~~$250.0~~$250 million of 11.250% Senior Notes ~~due 2023 (the “11.25% Senior Notes”)~~ to U.S.-based institutional investors. The net proceeds of $244.4 million were used to fully retire the Company’s 8.75% Senior Notes, ~~(as defined below),~~ which included principal, interest and a prepayment premium of approximately ~~$162.0~~$162 million. The remaining net proceeds were used to reduce borrowings under the Credit Facility.

The 11.25% Senior Notes mature on January 1, 2023, and bear interest at the rate of 11.25% per year, payable on January 1 and July 1 of each ~~year, beginning July 1, 2018.~~year. At any time prior to January 1, 2021, wethe Company may, on any one or more occasions, redeem up to 35% of the aggregate principal amount of the 11.25% Senior Notes with an amount of cash not greater than the net cash proceeds of certain equity offerings at a redemption price equal to 111.25% of the principal amounts redeemed, plus accrued and unpaid interest, provided that at least 65% of the aggregate principal amount of 11.25% Senior Notes originally issued remains outstanding immediately after such redemption and the redemption occurs within 180 days of the closing date of such equity offering.

At any time prior to January 1, 2021, wethe Company may, on any one or more occasions, redeem all or a part of the 11.25% Senior Notes at a redemption price equal to 100% of the principal amount redeemed, plus a “make-whole” premium as of, and accrued and unpaid interest.

On and after January 1, 2021, wethe Company may redeem the 11.25% Senior Notes, in whole or in part, plus accrued and unpaid interest, at the following redemption prices: 108.438% after January 1, 2021; 105.625% after January 1, 2022; and 100% after July 1, ~~2022.~~2022,

We did not make our interest payment on the 11.25% Senior Notes that was due on July 1, 2020 of approximately $14.1 million. We have 30 days to cure the default before the holders of the 11.25% Senior Notes or the trustee may be able to accelerate payment. The missed interest payment represents a current event of default under the Credit Facility. We have entered into the Forbearance Agreement which provides that, among other things, the lenders under the Credit Facility have agreed to forbear the Company’s default of the interest payment until July 31, 2020. However, the default under the Credit Facility has not been waived and still exists, and the Forbearance Agreement can be terminated if we fail to deliver a detailed restructuring proposal to the lenders by July 16, 2020. Accordingly, the amounts outstanding under the 11.25% Senior Notes as of March 31, 2020 were classified as current in the accompanying Condensed Consolidated Balance Sheet.

The indenture contains certain restrictions on ~~our~~the Company’s ability to incur additional debt, pay dividends on ~~our~~the Company’s common stock, make investments, create liens on ~~our~~the Company’s assets, engage in transactions with affiliates, transfer or sell assets, consolidate or ~~merger,~~merge, or sell substantially all of ~~our~~the Company’s assets.

~~Retirement of 8.75% Senior Notes~~

~~Using proceeds from the issuance~~ The indenture also contains cross- default provisions for defaults of the ~~11.25% Senior Notes, as discussed above, we fully retired~~Company's other debt instruments, including the ~~8.750% Senior Unsecured Notes due April 15, 2019 (“~~Credit Facility, caused by payment default or events which cause the ~~8.75% Senior Notes”). Pursuant~~acceleration of repayment prior to the ~~terms~~stated maturity of the indenture, the 8.75% Senior Notes were redeemed at 104.375% of the outstanding principal amount, or approximately $158.5 million, which excluded accrued interest. In connection with this transaction, we recognized a $8.6 million loss on extinguishment during the first quarter of 2018.

such instrument.

Capital Expenditures

We currently anticipate that our full-year ~~2019~~2020 capital budget, excluding acquisitions, will be approximately ~~$130~~$55 million ~~which~~to $65 million. This program will ~~primarily be used to drill~~allow for the drilling of a range of 10 gross (8.5 net) wells and ~~complete 20~~the completion of a range of 10 gross (7.0 net) wells, 15five of which were placed into production by the end of the ~~third~~first quarter ~~with~~of 2020 and an additional ~~two wells~~three at ~~Marquis~~Hawkeye which were placed into production ~~during October 2019. The~~by the end of June 2020.

The table below summarizes our cash capital expenditures incurred for the ~~nine~~three months ended ~~September 30, 2019:~~March 31, 2020:


In thousands	Nine Months Ended September 30, 2019		Three Months Ended March 31, 2020
Acquisition of oil and gas properties	$	5,239	$	816
Development of oil and gas properties	119,273		34,753
Purchases of other property and equipment	3,527		524
Total capital expenditures	$	128,039	$	36,093

For the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, our capital expenditures were funded with cash flow from operations, with additional funds provided by borrowings on our Credit Facility. Our ~~2019~~2020 capital expenditures may be further adjusted as business conditions warrant and the amount, timing and allocation of such expenditures is largely discretionary and within our control. The aggregate amount of capital that we will expend may fluctuate materially based on market conditions, the actual costs to drill, complete and place on production operated wells, our drilling results, other opportunities that may become available to us and our ability to obtain capital.

Critical Accounting Policies and Estimates

The preparation of our financial statements requires us to make estimates and judgments that can affect the reported amounts of assets, liabilities, revenues and expenses, as well as the disclosure of contingent assets and liabilities at the date of our financial statements. We analyze our estimates and judgments, including those related to oil, NGLs and natural gas revenues, oil and natural gas properties, impairment of long-lived assets, fair value of derivative instruments, asset and retirement obligations and income taxes, and we base our estimates and judgments on historical experience and various other assumptions that we believe to be reasonable under the circumstances. Actual results may vary from our estimates. The policies of particular importance to the portrayal of our financial position and results of operations and that require the application of significant judgment or estimates by our management are summarized in the Management’s Discussion and Analysis of Financial Condition and Results of Operations section of our Annual Report on Form 10-K as reported and filed with the SEC on ~~March~~April 13, ~~2019~~2020 (our ~~"2018~~"2019 10-K").

As of ~~September 30, 2019,~~March 31, 2020, there were no significant changes to any of our critical accounting policies and estimates.

Cautionary Note Regarding Forward-looking Statements

This Quarterly Report on Form 10-Q statement contains forward-looking statements that are subject to a number of known and unknown risks, uncertainties, and other important factors, many of which are beyond our control. We intend such forward-looking statements to be covered by the safe harbor provisions for forward-looking statements contained in Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical fact included in this Quarterly Report on Form 10-Q, regarding our strategy, future operations, financial position, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this Quarterly Report on Form 10-Q, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words.

Forward-looking statements may include statements about our:

Our ability to refinance or remedy any future default under our Credit Facility, refinance or satisfy the obligations of our 2023 Notes or obtain additional sources of capital;

discovery and development of crude oil, NGLs and natural gas reserves;

cash flows and liquidity;

business and financial strategy, budget, projections and operating results;

timing and amount of future production of crude oil, NGLs and natural gas;

amount, nature and timing of capital expenditures, including future development costs;

availability and terms of capital;

drilling, completion, and performance of wells;

timing, location and size of property acquisitions and divestitures;

costs of exploiting and developing our properties and conducting other operations;

general economic and business conditions; and

our plans, objectives, expectations and intentions.

All forward-looking statements speak only as of the date of this Quarterly Report on Form 10-Q. You should not place undue reliance on these forward-looking statements. Although we believe that our plans, objectives, expectations and intentions reflected in or suggested by the forward-looking statements we make in this Quarterly Report on Form 10-Q are reasonable, we can give no assurance that these plans, objectives, expectations or intentions will be achieved. We disclose important factors that could cause our actual results to differ materially from our expectations under Item 1A. Risk Factors, Item 8. Financial Statements and Supplementary Data and elsewhere in our ~~2018~~2019 Form 10-K, and Part I. Financial Information, Item 1A. Risk Factors and elsewhere in this Quarterly Report on Form 10-Q.

These important factors include risks related to:

variations in the market demand for, and prices of, crude oil, NGLs and natural gas;

proved reserves or lack thereof;

estimates of crude oil, NGLs and natural gas data;

the adequacy of our capital resources and liquidity including, but not limited to, access to additional borrowing to fund our operations;

borrowing capacity under our credit facility;

general economic and business conditions;

failure to realize expected value creation from property acquisitions;

uncertainties about our ability to find, develop or acquire additional oil and natural gas resources;

uncertainties with regard to our drilling schedules;

the expiration of leases on our undeveloped leasehold assets;

our dependence upon several significant customers for the sale of most of our crude oil, natural gas and NGL production;

counterparty credit risks;

competition within the crude oil and natural gas industry;

technology risks;

the concentration of our operations;

drilling results;

potential financial losses or earnings reductions from our commodity price risk management programs;

potential adoption of new governmental regulations;

our ability to satisfy future cash obligations and environmental costs; and

the other factors set forth under Risk Factors in Item 1A of Part I of our ~~2018~~2019 10-K.

The forward-looking statements relate only to events or information as of the date on which the statements are made in this Quarterly Report on Form 10-Q. Except as required by law, we undertake no obligation to update or revise publicly any forward-looking statements, whether as a result of new information, future events or otherwise, after the date on which the statements are made or to reflect the occurrence of unanticipated events.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

The following quantitative and qualitative disclosures about market risk are supplementary to the quantitative and qualitative disclosures provided in the Company’s Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019. As such, the information contained herein should be read in conjunction with the related disclosures in the Company’s Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019.

Commodity Price Risk

As a result of our operations, we are exposed to commodity price risk arising from fluctuations in the prices of crude oil, NGLs and natural gas. The demand for, and prices of, crude oil, NGLs and natural gas are dependent on a variety of factors, including supply and demand, weather conditions, the price and availability of alternative fuels, actions taken by governments and international cartels and global economic and political developments.

The following table shows the fair value of our derivative contracts and the hypothetical result from a 10% change in commodity prices as of ~~September 30, 2019.~~March 31, 2020. We remain at risk for possible changes in the market value of commodity derivative instruments; however, such risks could be mitigated by price changes in the underlying physical commodity:


			Hypothetical Fair Value							Hypothetical Fair Value
(in thousands)	Fair Value		10% Increase In Commodity Price			10% Decrease In Commodity Price		Fair Value		10% Increase In Commodity Price		10% Decrease In Commodity Price
Swaps	$	22,882	$	(2,123	)	$	47,888	$	99,859	$	80,624	$	119,094

Our board of directors reviews oil and natural gas hedging on a quarterly basis. Reports providing detailed analysis of our hedging activity are continually monitored. We sell our oil and natural gas on market using NYMEX market spot rates reduced for basis differentials in the basins from which we produce. We use swap contracts to manage our commodity price risk exposure. Our primary commodity risk management objectives are to protect returns on our drilling and completion activity as well as reduce volatility in our cash flows. Management makes recommendations on hedging that are approved by the board of directors before implementation. We enter into hedges for oil using NYMEX futures or over-the-counter derivative financial instruments with only certain well-capitalized counterparties which have been approved by our board of directors.

The result of oil market prices exceeding our swap prices or collar ceilings requires us to make payment for the settlement of our hedge derivatives, if owed by us, generally up to three business days before we receive market price cash payments from our customers. This could have a material adverse effect on our cash flows for the period between hedge settlement and payment for revenues earned.

Interest Rate Risk

As of ~~September 30, 2019,~~March 31, 2020, we had ~~$245.0~~$267.0 million outstanding under the Credit Facility, which is subject to floating market rates of interest. Borrowings under the Credit Facility bear interest at a fluctuating rate that is tied to an adjusted base rate or LIBOR, at our option. Any increase in this interest rate can have an adverse impact on our results of operations and cash flow. Based on borrowings outstanding at ~~September 30, 2019,~~March 31, 2020, a 100-basis-point change in interest rates would change our annualized interest expense by approximately ~~$2.5~~$2.7 million.

Counterparty and Customer Credit Risk

In connection with our hedging activity, we have exposure to financial institutions in the form of derivative transactions. The counterparties on our derivative instruments currently in place have investment-grade credit ratings. We expect that any future derivative transactions we enter into will be with these counterparties or our lenders under our Credit Facility that will carry an investment-grade credit rating.

We are also subject to credit risk due to concentration of our oil and natural gas receivables with certain significant customers. The inability or failure of our significant customers to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results. We review the credit rating, payment history and financial resources of our customers, but we do not require our customers to post collateral.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures.

As of the end of the period covered by this report, an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) was performed under the supervision and with the participation of management, including our Chief Executive Officer and Chief Accounting Officer. Based on that evaluation, our Chief Executive Officer and Chief Accounting Officer concluded that our disclosure controls and procedures were effective as of ~~September 30, 2019~~March 31, 2020 to ensure that information that is required to be disclosed in the reports the Company files and submits under the Securities Exchange Act of 1934 is recorded, that it is processed, summarized and reported within the time periods specified in the SEC’s rules and forms; and that information that is required to be disclosed under the Exchange Act is accumulated and communicated to management, including our Chief Executive Officer and our Chief Accounting Officer, as appropriate, to allow timely decisions regarding required disclosures.

~~Evaluation of~~ Changes in Internal Control over Financial Reporting.

~~Under~~During the ~~supervision and with the participation of our management, including our Chief Executive Officer and our Chief Accounting Officer, we have determined that, during the third~~first quarter of fiscal ~~2019,~~2020, there were no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II—OTHER INFORMATION

Item 1. Legal Proceedings.

From time to time, we are subject to legal proceedings and claims that arise in the ordinary course of business. Like other crude oil and gas producers and marketers, our operations are subject to extensive and rapidly changing federal and state environmental, health and safety, and other laws and regulations governing air emissions, wastewater discharges and solid and hazardous waste management activities. We are not aware of any pending or overtly threatened legal action against us that could have a material impact on our business.

Item 1A. Risk Factors.

~~Information with respect to the Company’s risk factors has been incorporated by reference~~Please refer to Item 1A of the ~~2018~~Company’s Annual Report on Form 10-K ~~which was filed on March 13,~~for the fiscal year ended December 31, 2019. There have been no material changes to our risk factors contained in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019, other than as detailed below.

The current outbreak of COVID-19 has adversely impacted our business, financial condition, liquidity and results of operations and is likely to have a continuing adverse impact for a significant period of time.

The COVID-19 pandemic has caused a rapid and precipitous drop in demand for oil, which in turn has caused oil prices to plummet since the first week of March 2020, negatively affecting the Company’s cash flow, liquidity and financial position. These events have worsened an already deteriorated oil market that resulted from the early-March 2020 failure by the group of oil producing nations known as OPEC+ to reach an agreement over proposed oil production cuts. Moreover, the uncertainty about the duration of the COVID-19 pandemic has caused storage constraints in the United States resulting from over-supply of produced oil, which is expected to significantly decrease our realized oil prices in the second quarter of 2020 and potentially beyond. Oil prices are expected to continue to be volatile as a result of these events and the ongoing COVID-19 outbreak, and as changes in oil inventories, oil demand and economic performance are reported. We cannot predict when oil prices will improve and stabilize.

The current pandemic and uncertainty about its length and depth in future periods has caused the realized oil prices we have received since February 2020 to be significantly reduced, adversely affecting our operating cash flow and liquidity. Although we have reduced our 2020 capital expenditures budget, our lower levels of cash flow may require us to shut-in production that has become uneconomic.

The COVID-19 pandemic is rapidly evolving, and the ultimate impact of this pandemic is highly uncertain and subject to change. The extent of the impact of the COVID-19 pandemic on our operational and financial performance will depend on future developments, including the duration and spread of the pandemic, its severity, the actions to contain the disease or mitigate its impact, related restrictions on travel, and the duration, timing and severity of the impact on domestic and global oil demand. The COVID-19 pandemic may also intensify the risks described in the other risk factors disclosed in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019.

Our failure to comply with any of the covenants under our 11.25% Senior Notes could cause an event of default under the 11.25% Senior Notes, and, due to cross-default provisions, currently represents an event of default in Credit Facility and could have a material adverse effect on our business.

We did not make the July 1, 2020 interest payment under our 11.25% Senior Notes and are currently in default. Such failure will represent an event of default under the 11.25% Senior Notes if not cured in 30 days after July 1, 2020 at which time the holders of the 11.25% Senior Notes or the trustee may accelerate payment under the notes. Such failure currently represents an event of default under our revolving credit facility. The Company ~~since~~has entered into the ~~filing~~Forbearance Agreement which provides that, among other things, the lenders under the Credit Facility have agreed to forbear the Company’s default of the interest payment until July 31, 2020. However, the default under the Credit Facility has not been waived and still exists, and the Forbearance Agreement can be terminated if the Company fails to deliver a detailed restructuring proposal to the lenders by July 16, 2020. In addition, the holders of the 11.25% Senior Notes have not agreed to waive or forbear the interest payment default. Accordingly, the amounts outstanding under the 11.25% Senior Notes as of March 31, 2020 were classified as current in the accompanying Condensed Consolidated Balance Sheet.

The Company has concluded that these circumstances create substantial doubt regarding its ability to continue as a going concern. The Company does not anticipate maintaining compliance with certain covenants under its Credit Facility over the next twelve months and may not be able to restructure, refinance or otherwise satisfy its obligations under the 11.25% Senior Notes. The Company is therefore evaluating the available financial alternatives, including obtaining acceptable alternative financing as well as seeking additional waivers, forbearances or amendments to the covenants or other provisions of the Credit Facility and the 11.25% Senior Notes to address any existing or future defaults and have engaged financial and legal advisors to assist the Company. If the Company is unable to reach an agreement with its lenders or find acceptable alternative financing, the lenders of the Credit Facility or the holders of the 11.25% Senior Notes may choose to accelerate repayment. If the Company's lenders or its noteholders accelerate the payment of amounts outstanding under our Credit Facility or the 11.25% Senior Notes, respectively, the Company does not currently have sufficient liquidity to repay such indebtedness and would need additional sources of capital to do so.

The Company cannot provide any assurances that it will be successful in any restructuring of existing debt obligations or obtaining capital sufficient to fund the refinancing of its outstanding indebtedness or to provide sufficient liquidity to meet its operating needs. If the Company is unsuccessful in its efforts to restructure and obtain new financing, it may be necessary for it to seek protection from creditors under Chapter 11, or an involuntary petition for bankruptcy may be filed against it.

We may be subject to United States Bankruptcy Court proceedings in the near future, which would pose significant risks to our business and to our investors.

As we do not anticipate maintaining compliance with all covenants under our Credit Facility over the next twelve months, we evaluating the available financial alternatives, including obtaining acceptable alternative financing as well as seeking additional waivers, forbearances or amendments to the covenants or other provisions of the Credit Facility to address any existing or future defaults, and we have engaged financial and legal advisors to assist us. However, we cannot provide any assurances that we will be successful in any restructuring of existing debt obligations or obtaining capital sufficient to fund the refinancing of our ~~2018 Form 10-K.~~outstanding indebtedness or to provide sufficient liquidity to meet our operating needs. If our attempts are unsuccessful or we are unable to complete such a restructuring on satisfactory terms, we may choose to pursue a filing under Chapter 11. If an agreement is reached and we decide to pursue a restructuring, it may be necessary for us and certain of our affiliates to file voluntary petitions for relief under Chapter 11 in order to implement a restructuring through a plan of reorganization before the bankruptcy court. We may also conclude that it is necessary to initiate Chapter 11 proceedings to implement a restructuring of our obligations if we are unable to reach an agreement with our creditors and other relevant parties regarding the terms of such a restructuring, or if further events or developments arise that necessitate us seeking relief under Chapter 11. It may be necessary to commence such a bankruptcy case in the near future. Also, if an agreement is not reached, certain creditors could commence involuntary bankruptcy cases against us if we are not able to satisfy our obligations under our debt agreements, including our Credit Facility and the 11.25% Senior Notes.

So long as a bankruptcy case continues, our senior management would be required to spend a significant amount of time and effort dealing with the reorganization instead of focusing exclusively on our business operations. Bankruptcy cases also might make it more difficult to retain management and other personnel necessary to the success and growth of our business. In addition, the longer a bankruptcy case continues, the more likely it is that our customers, dealers and suppliers would lose confidence in our ability to reorganize our businesses successfully and would seek to establish alternative commercial relationships.

It is not possible to predict the outcome of any bankruptcy case that may occur. In the event of a bankruptcy case, there can be no assurance that we would be able to restructure as a going concern or successfully propose or confirm a plan of reorganization that provides for the continuation of the business post-bankruptcy.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

~~None.~~The following table summarizes purchases of our Class A Common Stock during the first quarter of 2020:



	Total number of Shares Purchased	Average Price Paid per Share		Total Number of Shares that May Yet Be Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs
January 2020	—	—		—	—
February 2020	49,687	$	1.29	—	—
March 2020	67,932	0.45		—	—
Total	117,619			—

Stock repurchases during the first quarter of 2020 were made in connection with delivery by our employees of shares to us to satisfy their tax withholding requirements related to the vesting of restricted shares.

Item 3. Default under Credit Facility.

The Company did not satisfy the consolidated current ratio covenant under the Company’s Credit Facility (as defined below) as of the March 31, 2020 measurement date and such failure represents an event of default under the Company's Credit Facility. We have obtained a forbearance under the Credit Facility for this default, among others, pursuant to the Forbearance Agreement. Despite the forbearance, the defaults are continuing, and will continue, absent a waiver from the lenders. For more information regarding the Credit Facility, see “Part I, Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations-Liquidity and Capital Resources” and Note 1, Basis of Presentation - Going Concern.”

Item 5. Other Information

On June 29, 2020, the Company entered into Eligibility Notification Letters (the “Eligibility Notification Letters”) with each of our named executive officers, including Frank D. Bracken III, our chief executive officer and Barry D. Schneider, our chief operating officer, in connection with the Lonestar Resources US Inc. Change in Control Severance Plan (the “CIC Plan”) that was adopted by our board of directors. Under the Plan and the Eligibility Notification Letters, eligible participants will be entitled to severance payments and benefits in the event their employment is terminated by us without cause or they resign for good reason, in either case within two years following or two and one-half months prior to a change in control of the Company, subject to the participant’s execution and non-revocation of a release of claims in favor of the Company. For Mr. Bracken, the cash severance payments would be equal to three times his annual base salary and target bonus amount and monthly COBRA premiums for three years. For Mr. Schneider, the cash severance payments would be equal to two times his annual base salary and target bonus amount and monthly COBRA premiums for two years. In addition, each participant’s outstanding equity incentive awards would vest in full, subject to attainment of relevant performance goals for performance-based awards. The foregoing descriptions are qualified in their entirety to the text of the CIC Plan and Eligibility Notification Letters, the forms of which are attached as exhibits to this report.

Item 6. Exhibits.

Exhibit Number Description Incorporated by Reference
Filing
Date

Filed/
Furnished
Herewith
Form File No. Exhibit
10.1†
Lonestar Resources US Inc. Amended and Restated 2016 Incentive Plan, as amended as of May 23, 2019
8-K 001-37670 10.1 5/23/19
10.2
Borrowing Base Redetermination and Tenth Amendment to Credit Agreement
8-K 001-37670 10.1 6/17/19
31.1
Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer
*
31.2
Rule 13a-14(a)/15d-14(a) Certification of Chief Accounting Officer
*
32.1
Section 1350 Certification of Chief Executive Officer
**
32.2
Section 1350 Certification of Chief Accounting Officer
**
101.INS XBRL Instance Document *
101.SCH XBRL Taxonomy Extension Schema Document *
101.CAL XBRL Taxonomy Extension Calculation Linkbase Document *
101.DEF XBRL Taxonomy Extension Definition Linkbase Document *
101.LAB XBRL Taxonomy Extension Label Linkbase Document *
101.PRE XBRL Taxonomy Extension Presentation Linkbase Document *

Exhibit Number

Description

Incorporated by Reference

Filing

Date

Filed/

Furnished

Herewith

Form

File No.

Exhibit

10.1

Twelfth Amendment to Credit Agreement

8-K

001-37670

10.1

5/11/20

10.2

Waiver and Thirteenth Amendment to Credit Agreement

8-K

001-37670

10.1

6/17/20

10.3

Forbearance Agreement, Fourteenth Amendment, and Borrowing Base Agreement

10.4†

Lonestar Resources US. Inc. Change in Control Severance Plan

10.5†

Lonestar Resources US Inc. Change in Control Severance Plan Eligibility Notification (Executive)

31.1

Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer

31.2

Rule 13a-14(a)/15d-14(a) Certification of Chief Accounting Officer

32.1

Section 1350 Certification of Chief Executive Officer

32.2

Section 1350 Certification of Chief Accounting Officer

101.INS

XBRL Instance Document

101.SCH

XBRL Taxonomy Extension Schema Document

101.CAL

XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF

XBRL Taxonomy Extension Definition Linkbase Document

101.LAB

XBRL Taxonomy Extension Label Linkbase Document

101.PRE

XBRL Taxonomy Extension Presentation Linkbase Document


*	Filed herewith.


**	Furnished herewith


†	Management contract or compensatory plan or arrangement

SIGNATURES

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



	LONESTAR RESOURCES US INC.

~~November 12, 2019~~July 2, 2020		/s/ Frank D. Bracken, III
		Frank D. Bracken, III Chief Executive Officer

~~November 12, 2019~~July 2, 2020		/s/ Jason N. Werth
		Jason N. Werth Chief Accounting Officer

3843



In thousands	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
Operating Leases	$	68	$	205
Short-term leases⁽¹⁾	799		2,058
Total lease expense	$	867	$	2,263
Short-term lease costs capitalized to oil and gas properties⁽²⁾	$	4,904	$	9,827



In thousands, except lease term and discount rate data	September 30, 2019
Operating leases
Assets
Other property and equipment	$	112
Liabilities
Accrued liabilities	$	112
Weighted-average remaining lease term (years)	0.4
Weighted-average discount rate	5.0		%



In thousands	Nine Months Ended September 30, 2019
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	205
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	205