Creating sustainable value in responsible natural gas development from disciplined execution, growing scale and financial strength

Southwestern Energy Company (NYSE:SWN) today announced financial and operating results for the third quarter ended September 30, 2021.

Established scale positions in the two premier US natural gas basins by expanding operations into the Haynesville with the closing and integration of Indigo Natural Resources;
Generated $213 million net cash provided by operating activities, $396 million net cash flow (non-GAAP), and $105 million of free cash flow (non-GAAP);

- On track to exceed $475 million in free cash flow in 2021
Improved leverage ratio by 0.4x to 2.2x and expect to reduce leverage to approximately 2x by year-end;
Issued $1.2 billion of 5.375% senior notes due 2030, extending maturity runway and lowering cost of debt; received credit rating upgrade to BB by S&P;
Reported total production of 310 Bcfe, or 3.4 Bcfe per day, including one month of Haynesville production; total 2.7 Bcf per day of gas and 106 MBbls per day of liquids;
Achieved record SEC proved reserves (unaudited) of approximately 18.5 Tcfe; and
Received weighted average realized price (excluding impact of transportation and hedges) of $4.08 per Mcfe.

"Disciplined execution and financial strength defined the quarter for Southwestern Energy. Our team delivered financial and operating results which exceeded expectations, including the successful establishment of operations in Haynesville. Our team's proven capabilities in large scale consolidation and development are capturing the tangible benefits of scale from core positions in the two premier US gas basins. Our strategy continues to differentiate SWN and strengthen our position as a preferred investment opportunity for institutional investors seeking exposure to responsible natural gas development," said Bill Way, Southwestern Energy President and Chief Executive Officer.

Finance Update

The Company prioritizes protecting its financial strength and will continue the allocation of free cash flow to debt reduction and disciplined risk management. Given the current commodity price outlook and successful recent strategic actions, the Company has reduced its sustainable leverage target from 2x to a target range of 1.0x to 1.5x.

Within its disciplined risk management policy, the Company will target a level of hedges that protects the funding for capital investments and other financial priorities, including debt repayment. This approach to hedging safeguards the Company's financial strength while also retaining meaningful exposure to potential commodity price upside.

Financial Results

	For the three months ended						For the nine months ended
	September 30,						September 30,
(in millions)	2021			2020			2021			2020
Net loss	$	(1,857	)	$	(593	)	$	(2,386	)	$	(3,020	)
Adjusted net income (non-GAAP)	$	188		$	47		$	513		$	102
Diluted loss per share	$	(2.36	)	$	(1.04	)	$	(3.34	)	$	(5.48	)
Adjusted diluted earnings per share (non-GAAP)	$	0.24		$	0.08		$	0.72		$	0.18
Adjusted EBITDA (non-GAAP)	$	426		$	154		$	1,108		$	466
Net cash provided by operating activities	$	213		$	153		$	830		$	407
Net cash flow (non-GAAP)	$	396		$	135		$	1,022		$	413
Total capital investments ⁽¹⁾	$	291		$	223		$	816		$	705

(1)

Capital investments include an increase of $34 million and a decrease of $7 million for the three months ended September 30, 2021 and 2020, respectively, and increases of $63 million and $1 million for the nine months ended September 30, 2021 and 2020, respectively, relating to the change in accrued expenditures between periods.

For the quarter ended September 30, 2021, Southwestern Energy recorded a net loss of $1.86 billion, or ($2.36) per diluted share, compared to a net loss in 2020 of $593 million, or ($1.04) per diluted share. The quarter ended September 30, 2021 included a $2,011 million loss on unsettled derivatives, and the same period for 2020 included a $361 million non-cash impairment and a $289 million loss on unsettled derivatives.

Adjusted net income was $188 million, or $0.24 per diluted share, in the third quarter of 2021, compared to $47 million, or $0.08 per diluted share, for the prior year period. The increase was primarily related to a 40% increase in the weighted average realized price, including derivatives, and a 40% increase in production volumes, largely due to the Indigo and Montage acquisitions. Adjusted EBITDA (non-GAAP) was $426 million, net cash provided by operating activities was $213 million, net cash flow (non-GAAP) was $396 million and free cash flow (non-GAAP) was $105 million.

As indicated in the table below, third quarter 2021 weighted average realized price, including $0.34 per Mcfe of transportation expenses, was $3.74 per Mcfe, excluding the impact of derivatives. Including derivatives, weighted average realized price (including transportation) for the quarter was up 40% from $1.78 per Mcfe in 2020 to $2.49 per Mcfe in 2021, primarily due to higher commodity prices, including a 103% increase in NYMEX Henry Hub and a 72% increase in WTI, partially offset by the impact of settled derivatives. Third quarter 2021 weighted average realized price before transportation expense and excluding the impact of derivatives was $4.08 per Mcfe.

As of September 30, 2021, Southwestern Energy had total debt of $4.2 billion and a leverage ratio of 2.2x, an improvement of 0.4x compared to the previous quarter. At quarter end, the Company had $665 million of borrowings under its revolving credit facility with $159 million in letters of credit. The letters of credit decreased $74 million due to the Company's September 1^st S&P upgrade to BB credit rating.

During the quarter, the Company issued $1.2 billion of 5.375% senior notes due 2030 and utilized the proceeds to refinance higher coupon senior notes due 2025 and 2026 and to repay a portion of its revolver. The issuance extended the weighted average time to maturity of its senior notes to greater than 6 years and improved the weighted average cost of debt to approximately 6%.

Realized Prices	For the three months ended						For the nine months ended
(includes transportation costs)	September 30,						September 30,
	2021			2020			2021			2020
Natural Gas Price:
NYMEX Henry Hub price ($/MMBtu)⁽¹⁾	$	4.01		$	1.98		$	3.18		$	1.88
Discount to NYMEX ⁽²⁾	(0.83		)	(0.89		)	(0.74		)	(0.68		)
Realized gas price per Mcf, excluding derivatives	$	3.18		$	1.09		$	2.44		$	1.20
Gain on settled financial basis derivatives ($/Mcf)	0.11			0.12			0.11			0.06
Gain (loss) on settled commodity derivatives ($/Mcf)	(1.14		)	0.31			(0.43		)	0.39
Realized gas price, including derivatives ($/Mcf)	$	2.15		$	1.52		$	2.12		$	1.65
Oil Price:
WTI oil price ($/Bbl) ⁽³⁾	$	70.56		$	40.93		$	64.82		$	38.32
Discount to WTI	(8.24		)	(11.47		)	(8.71		)	(10.12		)
Realized oil price, excluding derivatives ($/Bbl)	$	62.32		$	29.46		$	56.11		$	28.20
Realized oil price, including derivatives ($/Bbl)	$	44.83		$	46.69		$	40.06		$	44.97
NGL Price:
Realized NGL price, excluding derivatives ($/Bbl)	$	31.76		$	10.34		$	26.05		$	8.37
Realized NGL price, including derivatives ($/Bbl)	$	19.31		$	10.50		$	17.13		$	9.85
Percentage of WTI, excluding derivatives	45		%	25		%	40		%	22		%
Total Weighted Average Realized Price:
Excluding derivatives ($/Mcfe)	$	3.74		$	1.34		$	3.01		$	1.36
Including derivatives ($/Mcfe)	$	2.49		$	1.78		$	2.41		$	1.86

(1)		Based on last day monthly futures settlement prices.
(2)		This discount includes a basis differential, a heating content adjustment, physical basis sales, third-party transportation charges and fuel charges, and excludes financial basis derivatives.
(3)		Based on the average daily settlement price of the nearby month futures contract over the period.

Operational Results

Total production for the quarter ended September 30, 2021 was 310 Bcfe, of which 81% was natural gas, 16% NGLs and 3% oil. Capital investments totaled $291 million for the third quarter, with 17 wells drilled, 23 wells completed and 24 wells placed to sales.

	For the three months ended				For the nine months ended
	September 30,				September 30,
	2021		2020		2021		2020
Production
Gas production (Bcf)	251		173		684		487
Oil production (MBbls)	1,729		1,294		5,222		3,776
NGL production (MBbls)	8,011		6,687		23,255		18,926
Total production (Bcfe)	310		221		855		623
Total production (Bcfe/day)	3.4		2.4		3.1		2.3

Average unit costs per Mcfe
Lease operating expenses ⁽¹⁾	$	0.95	$	0.91	$	0.94	$	0.93
General & administrative expenses ^(2,3)	$	0.09	$	0.12	$	0.11	$	0.13
Taxes, other than income taxes	$	0.11	$	0.07	$	0.10	$	0.06
Full cost pool amortization	$	0.43	$	0.29	$	0.37	$	0.40

(1)		Includes post-production costs such as gathering, processing, fractionation and compression.
(2)		Excludes $35 million and $39 million in merger-related expenses for the three and nine months ended September 30, 2021, respectively, and $7 million in restructuring charges for the nine months ended September 30, 2021.
(3)		Excludes $3 million in merger-related expenses for the three and nine months ended September 30, 2020, respectively, and $12 million in restructuring charges for the nine months ended September 30, 2020.

Appalachia – In the third quarter, total production was 280 Bcfe, with NGL production of 87 MBbls per day and oil production of 19 MBbls per day. The Company drilled 15 wells, completed 19 wells and placed 19 wells to sales with an average lateral length of 14,147 feet. During the third quarter, Appalachia well costs averaged under $630 per lateral foot for wells placed to sales, including approximately $550 per lateral foot in dry gas Marcellus. In the fourth quarter, the Company expects to average 2 rigs and 2 completion crews on its Appalachia properties, with activity in both dry gas and liquids rich areas.

Haynesville – The Company closed on the acquisition of its Haynesville assets on September 1, 2021, and as such, third quarter results include 30 days of production and activity. Production was 30 Bcf, or 1.0 Bcf per day. The Company drilled two wells, completed four wells and placed five wells to sales. All five wells placed to sales were in the highly economic Middle Bossier with an average initial production rate of 24 MMcf per day and an average lateral length of 6,326 feet. The Company expects to maintain the current rig and completion crew activity through the fourth quarter, placing 10 to 13 wells to sales.

E&P Division Results	For the three months ended September 30, 2021					For the nine months ended September 30, 2021
	Appalachia		Haynesville			Appalachia		Haynesville
Gas production (Bcf)		221		30			654		30
Liquids production
Oil (MBbls)		1,722		2			5,206		2
NGL (MBbls)		8,011		—			23,253		—
Production (Bcfe)		280		30			825		30

Gross operated production September 2021 (MMcfe/d)		4,147		1,325
Net operated production September 2021 (MMcfe/d)		3,038		1,016

Capital investments ($ in millions)
Drilling and completions, including workovers	$	176	$	52		$	591	$	52
Land acquisition and other		14		1			41		1
Capitalized interest and expense		34		6			109		6
Total capital investments	$	224	$	59		$	741	$	59

Gross operated well activity summary⁽¹⁾
Drilled		15		2			61		2
Completed		19		4			67		4
Wells to sales		19		5			67		5

Total weighted average realized price per Mcfe, excluding derivatives	$	3.68	$	4.33	⁽²⁾	$	2.96	$	4.33	⁽²⁾

(1)		For Haynesville, represents wells drilled, completed and placed to sales by Southwestern Energy after the close of the acquisition on September 1, 2021.
(2)		Haynesville weighted average realized price of $4.33 per Mcfe only includes sales beginning on September 1, 2021. The NYMEX Henry Hub price for September 2021 was $4.37 per MMBtu.

Wells to sales summary	For the three months ended September 30, 2021
	Gross wells to sales	Average lateral length
Appalachia
Super Rich Marcellus	5	14,473
Rich Marcellus	3	11,324
Dry Gas Utica	4	15,574
Dry Gas Marcellus	7	15,829
Haynesville⁽¹⁾	5	6,326
Total	24

(1)

Wells to sales following the close of the acquisition on September 1, 2021. Includes wells drilled and completed by previous operator.

Fourth Quarter 2021 Price Guidance

Based on current market conditions, Southwestern expects fourth quarter price differentials to be within the following ranges.

Natural gas discount to NYMEX including transportation ⁽¹⁾	$0.52 – $0.62 per Mcf
Natural gas liquids realization as a % of WTI including transportation	42% – 50%

(1)

Includes an estimated $0.03 to $0.06 per Mcfe gain on basis hedges.

Conference Call

Southwestern Energy will host a conference call on Thursday, November 4, 2021 at 10:00 a.m. Central to discuss third quarter 2021 results. To participate, dial US toll-free 877-883-0383, or international 412-902-6506 and enter access code 7695937. A live webcast will be available at ir.swn.com.

About Southwestern Energy

Southwestern Energy Company (NYSE:SWN) is a leading U.S. producer of natural gas and natural gas liquids focused on responsibly developing large-scale energy assets in the nation's most prolific shale gas basins. SWN's returns-driven strategy strives to create sustainable value for its stakeholders by leveraging its scale, financial strength and operational execution. For additional information, please visit www.swn.com and www.swn.com/responsibility.

Forward Looking Statement

Certain statements and information in this news release may constitute "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act, as amended. The words "believe," "expect," "anticipate," "plan," "predict," "intend," "seek," "foresee," "should," "would," "could," "attempt," "appears," "forecast," "outlook," "estimate," "project," "potential," "may," "will," "likely," "guidance," "goal," "model," "target," "budget" and other similar expressions are intended to identify forward-looking statements, which are generally not historical in nature. Statements may be forward looking even in the absence of these particular words. Examples of forward-looking statements include, but are not limited to our financial position, business strategy, production, reserve growth and other plans and objectives for our future operations, and generation of free cash flow. These forward-looking statements are based on our current expectations and beliefs concerning future developments and their potential effect on us. The forward-looking statements contained in this document are largely based on our expectations for the future, which reflect certain estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions, operating trends, and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. As such, management's assumptions about future events may prove to be inaccurate. For a more detailed description of the risks and uncertainties involved, see "Risk Factors" in our most recently filed Annual Report on Form 10-K, subsequent Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and other SEC filings. We do not intend to publicly update or revise any forward-looking statements as a result of new information, future events, changes in circumstances, or otherwise. These cautionary statements qualify all forward-looking statements attributable to us, or persons acting on our behalf. Management cautions you that the forward-looking statements contained herein are not guarantees of future performance, and we cannot assure you that such statements will be realized or that the events and circumstances they describe will occur. Factors that could cause actual results to differ materially from those anticipated or implied in the forward-looking statements herein include, but are not limited to: the timing and extent of changes in market conditions and prices for natural gas, oil and natural gas liquids ("NGLs"), including regional basis differentials and the impact of reduced demand for our production and products in which our production is a component due to governmental and societal actions taken in response to COVID-19 or other public health crises and any related company or governmental policies and actions to protect the health and safety of individuals or governmental policies or actions to maintain the functioning of national or global economies and markets; our ability to fund our planned capital investments; a change in our credit rating, an increase in interest rates and any adverse impacts from the discontinuation of the London Interbank Offered Rate; the extent to which lower commodity prices impact our ability to service or refinance our existing debt; the impact of volatility in the financial markets or other global economic factors; difficulties in appropriately allocating capital and resources among our strategic opportunities; the timing and extent of our success in discovering, developing, producing and estimating reserves; our ability to maintain leases that may expire if production is not established or profitably maintained; our ability to transport our production to the most favorable markets or at all; the impact of government regulation, including changes in law, the ability to obtain and maintain permits, any increase in severance or similar taxes, and legislation or regulation relating to hydraulic fracturing, climate and over-the-counter derivatives; the impact of the adverse outcome of any material litigation against us or judicial decisions that affect us or our industry generally; the effects of weather; increased competition; the financial impact of accounting regulations and critical accounting policies; the comparative cost of alternative fuels; credit risk relating to the risk of loss as a result of non-performance by our counterparties; and any other factors listed in the reports we have filed and may file with the SEC that are incorporated by reference herein. All written and oral forward-looking statements attributable to us are expressly qualified in their entirety by this cautionary statement.

Use of Non-GAAP Information

This news release contains non-GAAP financial measures, such as net cash flow, free cash flow, net debt and adjusted EBITDA, including certain key statistics and estimates. We report our financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide users of this financial information additional meaningful comparisons between current results and the results of our peers and of prior periods. Please see below for definitions of the non-GAAP financial measures that are based on reconcilable historical information.

Use of Projections

The financial, operational, industry and market projections, estimates and targets in this news release are forward-looking statements that are based on assumptions that are inherently subject to significant uncertainties and contingencies, many of which are beyond SWN's control. The assumptions and estimates underlying the projected, expected or target results are inherently uncertain and are subject to a wide variety of significant business, economic, regulatory and competitive risks and uncertainties that could cause actual results to differ materially from those contained in the financial, operational, industry and market projections, estimates and targets, including assumptions, risks and uncertainties described in "Forward-looking Statements" above.

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
	For the three months ended						For the nine months ended
	September 30,						September 30,
(in millions, except share/per share amounts)	2021			2020			2021			2020
Operating Revenues:
Gas sales	$	811		$	199		$	1,708		$	611
Oil sales	110			40			297			111
NGL sales	255			68			607			158
Marketing	418			219			1,102			645
Other	4			1			6			4
	1,598			527			3,720			1,529
Operating Costs and Expenses:
Marketing purchases	420			226			1,109			675
Operating expenses	296			202			805			577
General and administrative expenses	32			31			104			89
Merger-related expenses	35			3			39			3
Restructuring charges	—			—			7			12
Depreciation, depletion and amortization	138			70			334			267
Impairments	6			361			6			2,495
Taxes, other than income taxes	35			15			86			38
	962			908			2,490			4,156
Operating Income (Loss)	636			(381		)	1,230			(2,627		)
Interest Expense:
Interest on debt	56			43			154			123
Other interest charges	3			2			9			7
Interest capitalized	(25		)	(23		)	(68		)	(67		)
	34			22			95			63

Gain (Loss) on Derivatives	(2,399		)	(192		)	(3,461		)	38
Gain (Loss) on Early Extinguishment of Debt	(59		)	—			(59		)	35
Other Income (Loss), Net	(1		)	2			(1		)	3

Loss Before Income Taxes	(1,857		)	(593		)	(2,386		)	(2,614		)
Provision (Benefit) for Income Taxes:
Current	—			—			—			(2		)
Deferred	—			—			—			408
	—			—			—			406
Net Loss	$	(1,857	)	$	(593	)	$	(2,386	)	$	(3,020	)

Loss Per Common Share:
Basic	$	(2.36	)	$	(1.04	)	$	(3.34	)	$	(5.48	)
Diluted	$	(2.36	)	$	(1.04	)	$	(3.34	)	$	(5.48	)

Weighted Average Common Shares Outstanding:
Basic	787,032,414			571,872,413			713,455,662			551,162,559
Diluted	787,032,414			571,872,413			713,455,662			551,162,559

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
	September 30, 2021			December 31, 2020
ASSETS	(in millions)
Current assets:
Cash and cash equivalents	$	12			$	13
Accounts receivable, net	708				368
Derivative assets	130				241
Other current assets	52				49
Total current assets	902				671
Natural gas and oil properties, using the full cost method	31,486				27,261
Other	503				523
Less: Accumulated depreciation, depletion and amortization	(23,987		)		(23,673		)
Total property and equipment, net	8,002				4,111
Operating lease assets	144				163
Deferred tax assets	—				—
Other long-term assets	193				215
Total long-term assets	337				378
TOTAL ASSETS	$	9,241			$	5,160
LIABILITIES AND EQUITY
Current liabilities:
Current portion of long-term debt	$	201			$	—
Accounts payable	955				573
Taxes payable	78				74
Interest payable	42				58
Derivative liabilities	2,769				245
Current operating lease liabilities	41				42
Other current liabilities	76				20
Total current liabilities	4,162				1,012
Long-term debt	4,036				3,150
Long-term operating lease liabilities	101				117
Long-term derivative liabilities	960				183
Pension and other postretirement liabilities	31				45
Other long-term liabilities	237				156
Total long-term liabilities	5,365				3,651
Commitments and contingencies
Equity:
Common stock, $0.01 par value; 2,500,000,000 shares authorized; issued 1,059,331,421 shares as of September 30, 2021 and 718,795,700 shares as of December 31, 2020	11				7
Additional paid-in capital	6,688				5,093
Accumulated deficit	(6,749		)		(4,363		)
Accumulated other comprehensive loss	(34		)		(38		)
Common stock in treasury, 44,353,224 shares as of September 30, 2021 and December 31, 2020	(202		)		(202		)
Total equity/(deficit)	(286		)		497
TOTAL LIABILITIES AND EQUITY	$	9,241			$	5,160

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
	For the nine months ended
	September 30,
(in millions)	2021			2020
Cash Flows From Operating Activities:
Net loss	$	(2,386	)	$	(3,020	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	334			267
Amortization of debt issuance costs	6			6
Impairments	6			2,495
Deferred income taxes	—			408
Loss on derivatives, unsettled	2,952			272
Stock-based compensation	2			2
(Gain) loss on early extinguishment of debt	59			(35		)
Other	3			3
Change in assets and liabilities
Accounts receivable	(147		)	106
Accounts payable	58			(129		)
Taxes payable	(10		)	(12		)
Interest payable	(13		)	3
Inventories	(2		)	3
Other assets and liabilities	(32		)	38
Net cash provided by operating activities	830			407

Cash Flows From Investing Activities:
Capital investments	(747		)	(700		)
Proceeds from sale of property and equipment	4			2
Cash acquired in Indigo Acquisition	55			—
Cash paid in Indigo Acquisition	(373		)	—
Other	(1		)	—
Net cash used in investing activities	(1,062		)	(698		)

Cash Flows From Financing Activities:
Payments on long-term debt	(844		)	(72		)
Payments on revolving credit facility	(3,401		)	(1,449		)
Borrowings under revolving credit facility	3,366			1,415
Change in bank drafts outstanding	33			(9		)
Repayment of Indigo revolving credit facility	(95		)	—
Proceeds from issuance of long-term debt	1,200			350
Debt issuance/amendment costs	(25		)	(5		)
Proceeds from issuance of common stock, net	—			152
Cash paid for tax withholding	(3		)	(1		)
Net cash provided by financing activities	231			381

Increase (decrease) in cash and cash equivalents	(1		)	90
Cash and cash equivalents at beginning of year	13			5
Cash and cash equivalents at end of period	$	12		$	95

Hedging Summary

A detailed breakdown of derivative financial instruments and financial basis positions as of September 30, 2021 is shown below. Please refer to the Company's quarterly report on Form 10-Q to be filed with the Securities and Exchange Commission for complete information on the Company's commodity, basis and interest rate protection.

		Weighted Average Price per MMBtu
	Volume (Bcf)	Swaps		Sold Puts		Purchased Puts		Sold Calls
Natural gas
2021
Fixed price swaps	102	$	2.83	$	—	$	—	$	—
Two-way costless collars	88		—		—		2.70		3.04
Three-way costless collars	84		—		2.19		2.54		2.91
Total	274
2022
Fixed price swaps	539	$	2.77	$	—	$	—	$	—
Two-way costless collars	141		—		—		2.66		3.06
Three-way costless collars	333		—		2.06		2.51		2.94
Total	1,013
2023
Fixed price swaps	274	$	2.76	$	—	$	—	$	—
Two-way costless collars	83		—		—		2.69		2.92
Three-way costless collars	215		—		2.09		2.54		3.00
Total	572
2024
Fixed price swaps	57	$	2.43	$	—	$	—	$	—
Three-way costless collars	11		—		2.25		2.80		3.54
Total	68

	Volume	Weighted Average Strike Price
	*(Bcf)*	*($/MMBtu)*
Call Options – Natural Gas (Net)
2021	19	$	3.19
2022	77	$	3.00
2023	46	$	2.94
2024	9	$	3.00
Total	151
Swaptions – Natural Gas
2021⁽¹⁾	18	$	3.00

(1)

The Company has sold swaptions with an underlying tenor of January 2022 to December 2022, with an exercise date of December 23, 2021.

*Natural gas financial basis positions*	Volume	Basis Differential
	*(Bcf)*	*($/MMBtu)*
Q4 2021
Dominion South	28	$	(0.63	)
TCO	18	$	(0.49	)
TETCO M3	25	$	0.06
Total	71	$	(0.36	)
Q1 2022
Dominion South	25	$	(0.59	)
TCO	18	$	(0.49	)
TETCO M3	23	$	1.27
Total	66	$	0.07
Q2 2022
Dominion South	33	$	(0.58	)
TCO	20	$	(0.50	)
TETCO M3	24	$	(0.48	)
Total	77	$	(0.53	)
Q3 2022
Dominion South	33	$	(0.58	)
TCO	21	$	(0.51	)
TETCO M3	24	$	(0.49	)
Total	78	$	(0.54	)
Q4 2022
Dominion South	27	$	(0.61	)
TCO	21	$	(0.51	)
TETCO M3	15	$	(0.26	)
Total	63	$	(0.49	)

		Weighted Average Price per Bbl
	Volume (MBbls)	Swaps		Sold Puts		Purchased Puts		Sold Calls
Oil
2021
Fixed price swaps	780	$	48.94	$	—	$	—	$	—
Two-way costless collars	46		—		—		37.50		45.50
Three-way costless collars	550		—		39.18		48.95		54.35
Total	1,376
2022
Fixed price swaps	3,203	$	53.54	$	—	$	—	$	—
Three-way costless collars	1,380		—		39.89		50.23		57.05
Total	4,583
2023
Fixed price swaps	846	$	55.98	$	—	$	—	$	—
Three-way costless collars	1,268		—		33.97		45.51		56.12
Total	2,114
2024
Fixed price swaps	54	$	53.15	$	—	$	—	$	—
Ethane
2021
Fixed price swaps	2,483	$	9.74	$	—	$	—	$	—
Two-way costless collars	147		—		—		7.14		10.40
Total	2,630
2022
Fixed price swaps	3,361	$	10.01	$	—	$	—	$	—
Two-way costless collars	135		—		—		7.56		9.66
Total	3,496
Propane
2021
Fixed price swaps	2,107	$	23.98	$	—	$	—	$	—
2022
Fixed price swaps	4,471	$	26.96	$	—	$	—	$	—
Three-way costless collars	305		—		16.80		21.00		31.92
Total	4,776
Normal Butane
2021
Fixed price swaps	617	$	29.08	$	—	$	—	$	—
2022
Fixed price swaps	1,295	$	29.16	$	—	$	—	$	—
Natural Gasoline
2021
Fixed price swaps	635	$	43.62	$	—	$	—	$	—
2022
Fixed price swaps	1,256	$	46.41	$	—	$	—	$	—

Explanation and Reconciliation of Non-GAAP Financial Measures

The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.

One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.

Another such non-GAAP financial measure is free cash flow, which is defined as cash provided by operating activities, adjusting for changes in operating assets and liabilities, merger-related expenses and restructuring charges, less total capital investment. Management presents this measure because it is accepted as an indicator of excess cash flow available to a company for the repayment of debt or for other general corporate purposes, including the possible return of capital to shareholders.

Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share and adjusted EBITDA, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.

	Three Months Ended September 30,						Nine Months Ended September 30,
	2021			2020			2021			2020
Adjusted net income:	(in millions)
Net income (loss)	$	(1,857	)	$	(593	)	$	(2,386	)	$	(3,020	)
Add back (deduct):
Merger-related expenses		35			3			39			3
Restructuring charges		—			—			7			12
Impairments		6			361			6			2,495
Loss on unsettled derivatives		2,011			289			2,952			272
(Gain) loss on early extinguishment of debt		59			—			59			(35	)
Legal settlement charges		—			1			—			1
Other loss		—			1			—			—
Adjustments due to discrete tax items ⁽¹⁾		447			139			570			1,020
Tax impact on adjustments		(513	)		(154	)		(734	)		(646	)
Adjusted net income	$	188		$	47		$	513		$	102

(1)

2020 primarily relates to the recognition of a valuation allowance. The Company expects its 2021 income tax rate to be 24.3% before the impacts of any valuation allowance.

	Three Months Ended September 30,						Nine Months Ended September 30,
	2021			2020			2021			2020
Adjusted diluted earnings per share:
Diluted earnings (loss) per share	$	(2.36	)	$	(1.04	)	$	(3.34	)	$	(5.48	)
Add back (deduct):
Merger-related expenses		0.05			0.01			0.05			0.01
Restructuring charges		—			—			0.01			0.02
Impairments		0.01			0.63			0.01			4.50
Loss on unsettled derivatives		2.54			0.50			4.12			0.50
(Gain) loss on early extinguishment of debt		0.08			—			0.08			(0.06	)
Legal settlement charges		—			0.00			—			0.00
Other loss		—			0.00			—			—
Adjustments due to discrete tax items ⁽¹⁾		0.57			0.24			0.80			1.84
Tax impact on adjustments		(0.65	)		(0.26	)		(1.01	)		(1.15	)
Adjusted diluted earnings per share	$	0.24		$	0.08		$	0.72		$	0.18

(1)

2020 primarily relates to the recognition of a valuation allowance. The Company expects its 2021 income tax rate to be 24.3% before the impacts of any valuation allowance.

	Three Months Ended September 30,					Nine Months Ended September 30,
	2021		2020			2021		2020
Net cash flow:	(in millions)
Net cash provided by operating activities	$	213	$	153		$	830	$	407
Add back (deduct):
Changes in operating assets and liabilities		148		(21	)		146		(9	)
Merger-related expenses		35		3			39		3
Restructuring charges		—		—			7		12
Net cash flow	$	396	$	135		$	1,022	$	413

	Three Months Ended September 30, 2021
Free cash flow:	(in millions)
Net cash flow (as shown above)	$	396
Subtract:
Total capital investments	(291		)
Free cash flow	$	105

	Three Months Ended September 30,						Nine Months Ended September 30,
	2021			2020			2021			2020
Adjusted EBITDA:	(in millions)
Net loss	$	(1,857	)	$	(593	)	$	(2,386	)	$	(3,020	)
Add back (deduct):
Interest expense		34			22			95			63
Provision (benefit) for income taxes		—			—			—			406
Depreciation, depletion and amortization		138			70			334			267
Merger-related expenses		35			3			39			3
Restructuring charges		—			—			7			12
Impairments		6			361			6			2,495
Loss on unsettled derivatives		2,011			289			2,952			272
(Gain) loss on early extinguishment of debt		59			—			59			(35	)
Legal settlement charges		—			1			—			1
Stock-based compensation expense		—			—			2			2
Other loss		—			1			—			—
Adjusted EBITDA	$	426		$	154		$	1,108		$	466

	September 30, 2021
Net debt:	(in millions)
Total debt ⁽¹⁾	$	4,245
Subtract:
Cash and cash equivalents	(12		)
Net debt	$	4,233

(1)

Does not include $8 million of unamortized debt premium and issuance expense.

	September 30, 2021
Net debt to Adjusted EBITDA:	(in millions)
Net debt	$	4,233
Adjusted EBITDA ⁽¹⁾	$	1,897
Net debt to Adjusted EBITDA	2.2x

(1)

Adjusted EBITDA of $1,897 million for the twelve months ended September 30, 2021 includes $8 million of adjusted EBITDA generated by Indigo Natural Resources prior to the September 2021 acquisition and $505 million of adjusted EBITDA generated by Montage Resources prior to the November 2020 acquisition.

View source version on businesswire.com: https://www.businesswire.com/news/home/20211103006225/en/

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