Southwestern Energy Announces Third Quarter 2018 Results

Southwestern Energy Company (NYSE: SWN) today announced financial and operating results for the quarter ended September 30, 2018. Unless noted, results are compared to the third quarter of 2017.

Highlights

• Generated positive net cash flow after capital investment; full year capital guidance unchanged
• Reported net cash provided by operating activities of $307 million and net cash flow of $355 million, 45% and 43% higher, respectively
• Produced 252 Bcfe, including a 22% increase in Appalachia to 187 Bcfe
• Achieved record liquids production of 67.1 MBbls per day including 56.3 MBbls per day of NGLs and 10.8 MBbls per day of oil
• Captured $2.51 per Mcfe weighted average realized price, excluding hedges, with a 37% increase in Appalachia to $2.63 per Mcfe
• Drilled two record laterals of 15,559 feet in West Virginia and 16,272 feet in Pennsylvania
• Initiated share repurchase program, spending $25 million for 4.8 million shares
• Credit facility confirmed at $2.0 billion after Fayetteville sale
• Reported net loss attributable to common stock of $29 million, or $0.05 per diluted share, and adjusted net income attributable to common stock of $146 million, or $0.25 per diluted share

Bill Way, President and Chief Executive Officer of Southwestern Energy said, “This quarter’s cash flow was more than 40% higher than the same period last year. Results benefited from our returns focused growth of liquids as prices improved, from our leading low cost gas transportation portfolio as regional basis tightened and from operational achievements made by our leading operational team. In addition to building on our operational and financial momentum, we took another deliberate step in our strategy to reposition the Company by signing an agreement to sell the Fayetteville Shale assets.”

Way continued, “In addition to delivering strong quarterly results, we initiated the share repurchase program with an initial $25 million repurchase of shares and we completed a conditional $900MM debt tender that will significantly reduce near term debt maturities and leverage. Clearly, our team is executing and our strategy is working.”

Third Quarter 2018 Financial Results

FINANCIAL STATISTICS (Unaudited)			For the three months ended									For the nine months ended
			September 30,									September 30,
			2018					2017				2018				2017
Financial Results (in millions, except per share amounts)
Net income attributable to common stock			$	(29	)			$	43			$	229			$	548
Adjusted net income attributable to common stock (non-GAAP)			$	146				$	29			$	414			$	156
Adjusted EBITDA (non-GAAP)			$	377				$	269			$	1,090			$	899
Net cash provided by operating activities			$	307				$	211			$	971			$	789
Net cash flow (non-GAAP)			$	355				$	248			$	993			$	816
Total capital investments			$	298				$	331			$	1,039			$	946

Southwestern Energy generated record Appalachia production and benefited from higher realized pricing from gas, liquids and oil compared to the prior year. Including a non-cash impairment of $161 million, related to Fayetteville assets, primarily midstream, which were reclassified as held for sale, the Company reported a net loss attributable to common stock of $29 million or $0.05 per diluted share.

Adjusted net income attributable to common stock was $146 million, or $0.25 per diluted share for the quarter. Adjusted earnings before interest, taxes, depreciation and amortization (“adjusted EBITDA”) was $377 million, a 40% increase compared to 2017, primarily due to a 9% increase in production along with stronger realized gas, oil and NGL prices. The primary components of adjusted EBITDA included $276 million from Appalachia operations, $59 million from Fayetteville operations and $49 million from Midstream operations.

Improved Appalachia gas basis differentials and higher NGL prices drove Company-wide weighted average realized price 24% higher to $2.51 per Mcfe, compared to NYMEX gas price of $2.90 per MMbtu, excluding a hedging loss of $0.03 per Mcfe. Weighted average realized price includes transportation costs and basis differentials for gas, liquids and oil.

Increasing demand and tight fractionation capacity drove realized NGL prices 34% higher to $19.43 per barrel, including the impact of ethane and propane hedges. Realized oil price, including financial derivatives, of $59.96 per barrel was 48% higher and includes transportation costs, which remain in line with original guidance. Realized natural gas price for the Company, including hedges, was 10% higher at $2.16 per Mcf reflecting a 32% improvement in basis differentials, which were $0.76 per Mcf in the quarter compared to $1.11 per Mcf for the same period a year ago.

During the quarter, the Company announced the sale of Fayetteville Shale E&P and midstream assets for $1.865 billion subject to customary closing adjustments. Proceeds from the Fayetteville Shale will be used to reduce debt, continue a share repurchase program and continue development of its liquids-rich Appalachia assets. Upon the completion of the transaction, which is expected by year end 2018, the Company will retire $900 million in senior notes, as previously announced, reduce borrowings under the credit facility and will hold the remainder of proceeds in cash and short-term equivalents. The investments in Appalachia assets will be made in accordance with the Company’s strict capital allocation and internal return metrics.

Pursuant to the previously announced $200 million share repurchase program, the Company repurchased 4.8 million shares during the quarter at an average price of $5.18 per share.

At September 30, 2018, the Company reported liquidity of $1.5 billion including unused revolver capacity net of outstanding revolver borrowings and letters of credit. In October 2018, the Company’s bank group confirmed the borrowing base, adjusted for the sale of the Fayetteville assets, will be in excess of the Company’s $2.0 billion commitment under its credit facility.

A summary of the Company’s hedging position is provided in the attached financial tables. Additional information on physical basis sales, natural gas liquids and oil financial derivatives can be found in the 10-Q.

E&P Operational Review
Southwestern Energy’s net production for the third quarter was 9% higher at 252 Bcfe.

Appalachia Basin production was 22% higher at 187 Bcfe and was comprised of 20% liquids or 6,169 MBbls (67.1 MBbls per day) and 80% or 150 Bcf of natural gas (1.6 Bcf per day).

The Company invested $295 million in E&P capital, including $26 million related to the Southwest Appalachia water project, and drilled 22 wells, completed 23 wells and placed 35 wells to sales.

OPERATING STATISTICS			For the three months									For the nine months
			ended									ended
			September 30,									September 30,
			2018				2017					2018					2017
Production
Gas production (Bcf)				215				205					613					587
Oil production (MBbls)				998				663					2,334					1,747
NGL production (MBbls)				5,181				3,810					14,272					10,134
Total production (Bcfe)				252				232					712					658
Division Production
Northeast Appalachia (Bcf)				121				101					341					285
Southwest Appalachia (Bcfe)				66				52					172					131
Fayetteville Shale (Bcf)				65				78					199					241
Average unit costs per Mcfe
Lease operating expenses			$	0.92			$	0.91				$	0.93				$	0.90
General & administrative expenses(1)			$	0.18			$	0.23	(2)			$	0.19	(3)			$	0.22	(2)
Taxes, other than income taxes(1)			$	0.09			$	0.10				$	0.08				$	0.10
Full cost pool amortization			$	0.52			$	0.48				$	0.50				$	0.44

			(1)		Excludes restructuring charges
			(2)		Excludes $11 million of legal settlement charges for the three and nine months ended September 30, 2017.
			(3)		Excludes $8 million of legal settlement charges for the nine months ended September 30, 2018.

COMMODITY PRICES			For the three months ended										For the nine months ended
			September 30,										September 30,
			2018					2017					2018					2017
Natural Gas Price:
NYMEX Henry Hub Price ($/MMBtu) (1)			$	2.90				$	3.00				$	2.90				$	3.17
Discount to NYMEX (2)				(0.76	)				(1.11	)				(0.62	)				(0.86	)
Average realized gas price per Mcf, excluding derivatives			$	2.14				$	1.89				$	2.28				$	2.31
Gain (loss) on settled financial basis derivatives ($/Mcf)				(0.03	)				0.05					(0.04	)				(0.04	)
Gain (loss) on settled commodity derivatives ($/Mcf)				0.05					0.03					0.07					(0.05	)
Average realized gas price per Mcf, including derivatives			$	2.16				$	1.97				$	2.31				$	2.22
Oil Price:
WTI oil price ($/Bbl)			$	69.50				$	48.20				$	66.75				$	49.47
Discount to WTI				(8.30	)				(7.71	)				(7.24	)				(7.99	)
Average oil price per Bbl, excluding derivatives			$	61.20				$	40.49				$	59.51				$	41.48
Average oil price per Bbl, including derivatives			$	59.96				$	40.49				$	58.69				$	41.48
NGL Price:
Average net realized NGL price per Bbl, excluding derivatives			$	21.60				$	14.45				$	17.65				$	13.04
Average net realized NGL price per Bbl, including derivatives			$	19.43				$	14.47				$	16.75				$	13.06
Percentage of WTI				31	%				30	%				26	%				26	%
Average net realized C3+ price per Bbl, excluding derivatives			$	36.94				$	27.82				$	35.43				$	26.53
Average net realized C3+ price per Bbl, including derivatives			$	34.43				$	27.82				$	34.21				$	26.53
Percentage of WTI				53	%				58	%				53	%				54	%
Total Weighted Average Realized Price:
Excluding derivatives ($/Mcfe)			$	2.51				$	2.03				$	2.51				$	2.37
Including derivatives ($/Mcfe)			$	2.48				$	2.09				$	2.51				$	2.29

			(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.

Three Months Ended September 30, 2018 E&P Division Results			Appalachia												Fayetteville
			Northeast						Southwest						Shale
Production (Bcfe)				121						66						65
Gas Production (Bcf)				121						29						65
Liquids Production (MBbls)				–						6,169						–
NGL (MBbls)				–						5,180						–
Oil (MBbls)				–						989						–
Gross operated production as of September 2018 (MMcfe/d)				1,534						1,191						1,036
Net operated production as of September 2018 (MMcfe/d)				1,261						739						707
Capital investments ($ in millions)
Exploratory and development drilling, including workovers			$	85					$	112					$	1
Acquisition and leasehold				5						5						–
Seismic and other				1						1						1
Capitalized interest and expense				9						38						3
Total capital investments			$	100					$	156					$	5
Gross operated well activity summary
Drilled				9						13						–
Completed				10						13						–
Wells to sales				18						17						–
Average completed well cost (in millions)			$	7.0		(1)			$	8.6		(1)			$	–
Average lateral length (in ft)				6,960						6,994		(2)				–
Realized Natural Gas Price
NYMEX Henry Hub Price ($/MMBtu)			$	2.90					$	2.90					$	2.90
Discount to NYMEX (3)				(0.81	)					(0.62	)					(0.75	)
Average realized gas price per Mcf, excluding derivatives			$	2.09					$	2.28					$	2.15
Total weighted average realized price per Mcfe, excluding derivatives			$	2.09					$	3.62					$	2.15

			(1)		Average completed well cost includes Marcellus wells only and amounts for delineation and science
			(2)		Average lateral length includes Marcellus wells only
			(3)		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

Southwest Appalachia – Total net production of 66 Bcfe, was 27% higher than the prior year quarter and was comprised of 52% liquids. NGL and oil production averaged 56.3 MBbls per day and 10.8 MBbls per day, totaling 67.1 MBbls per day liquids.

Weighted average realized price on a natural gas equivalent basis was $3.62 per Mcf, a $0.72 per Mcfe uplift compared to a NYMEX gas price of $2.90 per Mcf.

The Company placed 16 Marcellus wells to sales with an average lateral length of 6,994 feet. Fourteen wells were located in the super rich acreage and online for at least 30 days, had an average 30-day rate of 7.9 MMcfe per day with a 43% NGL, 23% oil and 34% gas mix. Two wells in the rich acreage were online for at least 30 days and had an average 30-day rate of 13.4 MMcfe per day with a 44% NGL and 56% gas mix.

During the quarter, the Company drilled a West Virginia state record well lateral of 15,559 feet in the super rich area, which is expected to be online early next year.

The first Upper Devonian well was drilled in the Company’s liquids-rich acreage and brought online in the third quarter. This well continues to show encouraging, early results with 45% liquids. The Company plans to bring additional Upper Devonian wells online in the fourth quarter to support its ongoing delineation program.

Northeast Appalachia – Total net production of 121 Bcf, or 1.3 Bcf per day, was 20% higher than the third quarter of 2017. The Company placed 18 wells to sales with an average lateral length of 6,960 feet, 14 of which were online for 30 days and had an average 30-day rate of 13.7 MMcf per day. This includes four short laterals associated with a “wine rack” test.

The longest lateral in the Company’s history, the Mitchell South 2H well, was successfully drilled at 16,272 feet, and is expected to be online in the fourth quarter.

Realized price, which includes transportation costs, was $2.09 per Mcf, a 30% improvement due to tightening basis differentials driven by takeaway capacity going in-service to markets outside of the area. In addition to the ongoing benefit of regional basis improvements, the Company maintains a leading low cost firm transportation portfolio to premium markets that supply low cost natural gas to northeast US markets.

Conference Call
Southwestern Energy will host a conference call and webcast on Friday, October 26, 2018 at 9:00 a.m. Central to discuss third quarter 2018 results. To participate, dial US toll-free 877-883-0383, or international 412-902-6505 and enter access code 3794459. The conference call will webcast live at www.swn.com.

To listen to a replay of the call, dial 877-344-7529, International 412-317-0088, or Canada Toll Free 855-669-9658. Enter replay access code 10124794. The replay will be available until November 20, 2018.

About Southwestern Energy
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on our website: www.swn.com.

Forward Looking Statement
This news release contains forward-looking statements. Forward-looking statements relate to future events and anticipated results of operations, business strategies, and other aspects of our operations or operating results. In many cases you can identify forward-looking statements by terminology such as “anticipate,” “intend,” “plan,” “project,” “estimate,” “continue,” “potential,” “should,” “could,” “may,” “will,” “objective,” “guidance,” “outlook,” “effort,” “expect,” “believe,” “predict,” “budget,” “projection,” “goal,” “forecast,” “target” or similar words. Statements may be forward looking even in the absence of these particular words. Where, in any forward-looking statement, the Company expresses an expectation or belief as to future results, such expectation or belief is expressed in good faith and believed to have a reasonable basis. However, there can be no assurance that such expectation or belief will result or be achieved. The actual results of operations can and will be affected by a variety of risks and other matters including, but not limited to, changes in commodity prices (including geographic basis differentials); changes in expected levels of natural gas and oil reserves or production, or the Company’s ability to consummate the closing of the sale of its Fayetteville Shale assets; operating hazards, drilling risks, unsuccessful exploratory activities; natural disasters; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases in service or other costs related to drilling and completion activities; potential liability for remedial actions under existing or future environmental regulations; failure to obtain necessary regulatory approvals; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws, including court rulings, applicable to our business. Other factors that could cause actual results to differ materially from those described in the forward-looking statements include other economic, business, competitive and/or regulatory factors affecting our business generally as set forth in our filings with the Securities and Exchange Commission. Unless legally required, Southwestern Energy Company undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
		For the three months ended								For the nine months ended
		September 30,								September 30,
		2018				2017				2018				2017
(in millions, except share/per share amounts)
Operating Revenues
Gas sales		$	465			$	394			$	1,412			$	1,368
Oil sales			62				27				141				73
NGL sales			112				55				252				132
Marketing			287				233				805				736
Gas gathering			25				28				73				85
Other			–				–				4				–
			951				737				2,687				2,394
Operating Costs and Expenses
Marketing purchases			288				236				808				740
Operating expenses			206				170				588				481
General and administrative expenses			51				62				165				170
Restructuring charges			2				–				20				–
Depreciation, depletion and amortization			151				135				436				364
Impairments			161				–				161				–
Taxes, other than income taxes			26				24				64				75
			885				627				2,242				1,830
Operating Income			66				110				445				564
Interest Expense
Interest on debt			56				58				180				175
Other interest charges			2				2				6				7
Interest capitalized			(29	)			(29	)			(86	)			(85	)
			29				31				100				97
Gain (Loss) on Derivatives			(65	)			45				(108	)			295
Loss on Early Extinguishment of Debt			–				(59	)			(8	)			(70	)
Other Income (Loss), Net			–				(2	)			2				6
Income Before Income Taxes			(29	)			63				230				698
Provision (Benefit) for Income Taxes
Current			–				(10	)			–				(10	)
Deferred			–				(4	)			–				(4	)
			–				(14	)			–				(14	)
Net Income		$	(29	)		$	77			$	230			$	712
Mandatory convertible preferred stock dividend			–				27				–				81
Participating securities - mandatory convertible preferred stock			–				7				1				83
Net Income Attributable to Common Stock		$	(29	)		$	43			$	229			$	548
Income Per Common Share
Basic		$	(0.05	)		$	0.09			$	0.40			$	1.11
Diluted		$	(0.05	)		$	0.09			$	0.39			$	1.10
Weighted Average Common Shares Outstanding
Basic			581,171,753				499,812,926				577,912,421				496,458,435
Diluted			581,171,753				502,290,779				579,828,858				498,527,671

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
		September 30, 2018				December 31, 2017
ASSETS		(in millions)
Current assets:
Cash and cash equivalents		$	9			$	916
Accounts receivable, net			397				428
Derivative assets			104				130
Other current assets			41				35
Current assets held for sale			64				–
Total current assets			615				1,509
Natural gas and oil properties, using the full cost method, including $1,767 million as of September 30, 2018 and $1,817 million as of December 31, 2017 excluded from amortization			24,880				23,890
Gathering systems			38				1,315
Other			479				564
Less: Accumulated depreciation, depletion and amortization			(19,928	)			(19,997	)
Total property and equipment, net			5,469				5,772
Other long-term assets			194				240
Long-term assets held for sale			780				–
TOTAL ASSETS		$	7,058			$	7,521
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable		$	563			$	533
Taxes payable			32				62
Interest payable			60				70
Dividends payable			–				27
Derivative liabilities			111				64
Other current liabilities			10				24
Current liabilities held for sale			116				–
Total current liabilities			892				780
Long-term debt			3,572				4,391
Pension and other postretirement liabilities			50				58
Other long-term liabilities			162				313
Long-term liabilities held for sale			177				–
Total long-term liabilities			3,961				4,762
Equity:
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 586,195,162 shares as of September 30, 2018 and 512,134,311 as of December 31, 2017			6				5
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of December 31, 2017, converted to common stock on January 12, 2018			–				–
Additional paid-in capital			4,714				4,698
Accumulated deficit			(2,449	)			(2,679	)
Accumulated other comprehensive loss			(40	)			(44	)
Common stock in treasury; 4,860,280 shares as of September 30, 2018 and 31,269 shares as of December 31, 2017			(26	)			(1	)
Total equity			2,205				1,979
TOTAL LIABILITIES AND EQUITY		$	7,058			$	7,521

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
		For the nine months ended
		September 30,
		2018				2017
		(in millions)
Cash Flows From Operating Activities:
Net income		$	230			$	712
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization			436				364
Amortization of debt issuance costs			6				7
Impairments			161				–
Deferred income taxes			–				(4	)
(Gain) loss on derivatives, unsettled			113				(350	)
Stock-based compensation			12				19
Loss on early extinguishment of debt			8				70
Other			7				(2	)
Change in assets and liabilities			(2	)			(27	)
Net cash provided by operating activities			971				789
Cash Flows From Investing Activities:
Capital investments			(1,008	)			(943	)
Proceeds from sale of property and equipment			9				17
Other			4				5
Net cash used in investing activities			(995	)			(921	)
Cash Flows From Financing Activities:
Payments on short-term debt			–				(287	)
Payments on long-term debt			(1,191	)			(1,139	)
Payments on revolving credit facility			(1,122	)			–
Borrowings under revolving credit facility			1,482				–
Change in bank drafts outstanding			10				–
Proceeds from issuance of long-term debt			–				1,150
Debt issuance costs			(9	)			(18	)
Purchase of treasury stock			(25	)			–
Preferred stock dividend			(27	)			(8	)
Cash paid for tax withholding			(1	)			–
Net cash used in financing activities			(883	)			(302	)
Decrease in cash and cash equivalents			(907	)			(434	)
Cash and cash equivalents at beginning of year			916				1,423
Cash and cash equivalents at end of period		$	9			$	989

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES
SEGMENT INFORMATION
(Unaudited)
		Exploration and Production					Midstream Services						Other				Eliminations				Total
		(in millions)
Three months ended September 30, 2018
Revenues		$	633				$	912					$	–			$	(594	)		$	951
Marketing purchases			–					833						–				(545	)			288
Operating expenses			232					23						–				(49	)			206
General and administrative expenses			44					7						–				–				51
Restructuring charges			2					–						–				–				2
Depreciation, depletion and amortization			140					11						–				–				151
Impairments			15					145						1				–				161
Taxes, other than income taxes			25					1						–				–				26
Operating income (loss)			175					(108	)					(1	)			–				66
Capital investments (1)			295					–						3				–				298
Three months ended September 30, 2017
Revenues		$	470				$	734					$	–			$	(467	)		$	737
Marketing purchases			–					645						–				(409	)			236
Operating expenses			210					18						–				(58	)			170
General and administrative expenses			54	(2)				8						–				–				62
Depreciation, depletion and amortization			120					15						–				–				135
Taxes, other than income taxes			22					2						–				–				24
Operating income			64					46						–				–				110
Capital investments (1)			320					9						2				–				331
Nine months ended September 30, 2018
Revenues		$	1,790				$	2,605					$	–			$	(1,708	)		$	2,687
Marketing purchases			–					2,368						–				(1,560	)			808
Operating expenses			660					76						–				(148	)			588
General and administrative expenses			145	(2)				20						–				–				165
Restructuring charges			18					2						–				–				20
Depreciation, depletion and amortization			383					53		(3)				–				–				436
Impairments			15					145						1								161
Taxes, other than income taxes			59					5						–				–				64
Operating income (loss)			510					(64	)					(1	)			–				445
Capital investments (1)			1,025					9						5				–				1,039
Nine months ended September 30, 2017
Revenues		$	1,559				$	2,414					$	–			$	(1,579	)		$	2,394
Marketing purchases			–					2,141						–				(1,401	)			740
Operating expenses			591					68						–				(178	)			481
General and administrative expenses			147	(2)				23						–				–				170
Depreciation, depletion and amortization			317					47						–				–				364
Taxes, other than income taxes			69					6						–				–				75
Operating income			435					129						–				–				564
Capital investments (1)			921					21						4				–				946

(1)			Capital investments include decreases of $31 million and $2 million for the three months ended September 30, 2018 and 2017, respectively, and an increase of $21 million and a decrease of $13 million for the nine months ended September 30, 2018 and 2017, respectively, relating to the change in capital accruals between periods.
(2)			Includes $8 million of legal settlement charges for the nine months ended September 30, 2018 and includes $11 million of legal settlement charges for the three and nine months ended September 30, 2017, respectively.
(3)			Includes a $10 million impairment related to certain non-core gathering assets.

Hedging Summary

A detailed breakdown of the Company’s derivative financial instruments and financial basis positions as of September 30, 2018 is shown below. Please refer to our 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.

Financial protection on production				Weighted Average Price per MMBtu
		Volume					Sold			Purchased			Sold
		(Bcf)		Swaps			Puts			Puts			Calls
Natural Gas
2018
Sold fixed price swaps		42		$	2.91		$	–		$	–		$	–
Two-way costless collars		6			–			–			2.90			3.27
Three-way costless collars		72			–			2.40			2.97			3.37
Total		120
2019
Sold fixed price swaps		156		$	2.92		$	–		$	–		$	–
Two-way costless collars		53			–			–			2.80			2.98
Three-way costless collars		163			–			2.47			2.89			3.26
Total		372
2020
Sold fixed price swaps		2		$	2.77		$	–		$	–		$	–
Three-way costless collars		47			–			2.43			2.80			3.09
Total		49

Financial protection on production				Weighted Average
		Volume		Strike Price per
		(Bcf)		Bbl
Propane
2018
Sold fixed price swaps		778		$	34.86
2019
Sold fixed price swaps		1,506		$	32.63
Ethane
2018
Sold fixed price swaps		1,389		$	13.30
2019
Sold fixed price swaps		3,322			13.38

Other Derivative Contracts				Weighted Average
		Volume		Strike Price per
		(Bcf)		MMBtu
Purchased Call Options - Natural Gas
2020		68		$	3.63
2021		57			3.52
Total		125
Sold Call Options - Natural Gas
2018		16		$	3.50
2019		52			3.50
2020		136			3.39
2021		114			3.33
Total		318

Financial basis positions		Volume		Basis Differential
(excludes physical positions)		(Bcf)		($/MMbtu)
Q4 2018
Dominion South		10		$	(0.64	)
TETCO M3		6			(0.41	)
Total		16		$	(0.55	)
2019
Dominion South		12		$	(0.54	)
TETCO M3		16			0.98
TCO		4			(0.38	)
Total		32		$	0.23

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.

Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, 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.

See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three and nine months ended September 30, 2018 and September 30, 2017, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.

		3 Months Ended September 30,
		2018				2017
		(in millions)
Net income attributable to common stock:
Net income (loss) attributable to common stock		$	(29	)		$	43
Add back:
Participating securities - mandatory convertible preferred stock			–				2
Impairment			161				–
Restructuring charges			2				–
(Gain) loss on certain derivatives			59				(31	)
Loss on early extinguishment of debt			–				59
Legal settlement charges			–				5
Adjustments due to discrete tax items (1)			8				(37	)
Tax impact on adjustments			(55	)			(12	)
Adjusted net income attributable to common stock		$	146			$	29

(1)			Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance.

		9 Months Ended September 30,
		2018				2017
		(in millions)
Net income attributable to common stock:
Net income attributable to common stock		$	230			$	548
Add back:
Participating securities - mandatory convertible preferred stock			(1	)			59
Impairments			171				–
Restructuring charges			20				–
(Gain) loss on certain derivatives			113				(350	)
Gain on sale of assets, net			(1	)			(3	)
Loss on early extinguishment of debt			8				70
Legal settlement charges			8				5
Adjustments due to inventory valuation and other			1				(1	)
Adjustments due to discrete tax items (1)			(56	)			(279	)
Tax impact on adjustments			(79	)			107
Adjusted net income attributable to common stock		$	414			$	156

(1)			Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance.

		3 Months Ended September 30,
		2018				2017
Diluted earnings per share:
Diluted earnings per share		$	(0.05	)		$	0.09
Add back:
Participating securities - mandatory convertible preferred stock			–				–
Impairments			0.28				–
Restructuring charges			–				–
(Gain) loss on certain derivatives			0.10				(0.06	)
Loss on early extinguishment of debt			–				0.12
Legal settlement charges			–				0.01
Adjustments due to inventory valuation and other			–				–
Adjustments due to discrete tax items (1)			0.01				(0.07	)
Tax impact on adjustments			(0.09	)			(0.03	)
Adjusted diluted earnings per share		$	0.25			$	0.06

(1)			Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance.

		9 Months Ended September 30,
		2018				2017
Diluted earnings per share:
Diluted earnings per share		$	0.39			$	1.10
Add back:
Participating securities - mandatory convertible preferred stock			–				0.12
Impairments			0.30				–
Restructuring charges			0.04				–
(Gain) loss on certain derivatives			0.19				(0.70	)
Gain on sale of assets, net			–				(0.01	)
Loss on early extinguishment of debt			0.01				0.14
Legal settlement charges			0.01				0.01
Adjustments due to inventory valuation and other			–				–
Adjustments due to discrete tax items (1)			(0.10	)			(0.56	)
Tax impact on adjustments			(0.13	)			0.21
Adjusted diluted earnings per share		$	0.71			$	0.31

(1)			Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance.

		3 Months Ended September 30,
		2018			2017
		(in millions)
Net cash flow provided by operating activities:
Net cash provided by operating activities		$	307		$	211
Add back:
Changes in operating assets and liabilities			46			37
Restructuring charges			2			–
Net cash flow		$	355		$	248
		9 Months Ended September 30,
		2018			2017
		(in millions)
Net cash provided by operating activities:
Net cash provided by operating activities		$	971		$	789
Add back:
Changes in operating assets and liabilities			2			27
Restructuring charges			20			–
Net cash flow		$	993		$	816

		3 Months Ended September 30,
		2018				2017
		(in millions)
EBITDA:
Net income		$	(29	)		$	77
Add back:
Interest expense			29				31
Income tax benefit			–				(14	)
Depreciation, depletion and amortization			151				135
Impairments			161				–
Restructuring charges			2				–
Gain on sale of assets, net			–				–
Loss on early extinguishment of debt			–				59
Legal settlement charges			–				5
(Gain) loss on certain derivatives			59				(31	)
Stock based compensation expense			4				9
Adjusted EBITDA		$	377			$	271
		9 Months Ended September 30,
		2018				2017
		(in millions)
EBITDA:
Net income		$	230			$	712
Add back:
Interest expense			100				97
Income tax benefit			–				(14	)
Depreciation, depletion and amortization			436				364
Impairments			161				–
Restructuring charges			20				–
Gain on sale of assets, net			(1	)			(3	)
Loss on early extinguishment of debt			8				70
Legal settlement charges			8				5
(Gain) loss on certain derivatives			113				(350	)
Adjustments due to inventory valuation and other			2				(1	)
Stock based compensation expense			13				22
Adjusted EBITDA		$	1,090			$	902

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View source version on businesswire.com: https://www.businesswire.com/news/home/20181025006073/en/

Source: Business Wire (October 25, 2018 - 5:26 PM EDT)

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