Business Wire | Jul 30, 2020 04:22PM EDT

Southwestern Energy Announces Second Quarter 2020 Results

Jul. 30, 2020

SPRING, Texas--(BUSINESS WIRE)--Jul. 30, 2020--Southwestern Energy Company (NYSE: SWN) today announced financial and operating results for the second quarter ended June 30, 2020.

* Broad-based cost elimination with full year expense savings totaling $90 million, up $30 million since last quarter; * Achieved record single-well cost of $505 per lateral foot; expect to average $650 per foot in the second half of the year; * Revised annual capital guidance to $860 million - $915 million, lowering high end of range; * Shallowed annual base decline to 23%; * Delivered total production of 201 Bcfe; including 1.7 Bcf per day of gas and 79 MBbls per day of liquids; * Realized $120 million in cash settlements from the hedging program across all commodities, a $0.60 per Mcfe benefit; reported weighted average realized price (excluding transportation) of $2.05 per Mcfe including derivatives; and * Repurchased $27 million senior notes at a 24% discount; year-to-date senior note repurchases total $107 million at a 33% discount.

"Southwestern Energy again underscored its strength and resilience during the second quarter. We mitigated many of the far-reaching impacts of COVID-19 on the industry with operational agility and commercial flexibility to achieve results at or above our commitments. These actions support our return to a self-funded capital program in 2021," said Bill Way, Southwestern Energy President and Chief Executive Officer.

"We delivered comprehensive cost reductions, improved our base decline and lowered well costs, all ahead of expectations. This progress, along with our dynamic hedge portfolio and returns-focused capital allocation practice, solidly moves us forward on our path to deliver sustainable long-term value," continued Way.

Financial Results

For the quarter ended June 30, 2020, Southwestern Energy recorded a net loss of $880 million, or ($1.63) per diluted share, including $655 million of non-cash impairments and a $229 million non-cash loss on unsettled mark-to-market derivatives. This compares to net income of $138 million, or $0.26 per diluted share in the second quarter of 2019. Adjusted net income (loss) (non-GAAP), which excludes the non-cash items noted above, was a $1 million loss, or ($0.00) per diluted share in the second quarter of 2020, compared to adjusted net income of $40 million, or $0.08 per diluted share for the prior year period. The decrease in adjusted net income (loss) was primarily related to a 47% decrease in average realized price, partially offset by $120 million in cash settled derivative gains in 2020 and a $31 million decrease in depreciation, depletion and amortization expense. Adjusted EBITDA (non-GAAP) was $106 million, net cash provided by operating activities was $94 million and net cash flow (non-GAAP) was $87 million.

FINANCIAL STATISTICS For the three months For the six months ended ended

June 30, June 30,

(in millions) 2020 2019 2020 2019

Net income (loss) $ (880 ) $ 138 $ (2,427 ) $ 732

Adjusted net income (loss) $ (1 ) $ 40 $ 55 $ 185 (non-GAAP)

Diluted earnings (loss) per share $ (1.63 ) $ 0.26 $ (4.49 ) $ 1.35

Adjusted diluted earnings per $ (0.00 ) $ 0.08 $ 0.10 $ 0.34 share (non-GAAP)

Adjusted EBITDA (non-GAAP) $ 106 $ 186 $ 312 $ 505

Net cash provided by operating $ 94 $ 101 $ 254 $ 543 activities

Net cash flow (non-GAAP) $ 87 $ 173 $ 278 $ 482

Total capital investments ^(1) $ 245 $ 368 $ 482 $ 693

Capital investments includes an increase of $39 million for the three months ended June 30, 2019, and increases of $8 million and $105 million(1) for the six months ended June 30, 2020 and 2019, respectively, relating to the change in capital accruals between periods. There was no change in the capital accrual for the three months ended June 30, 2020.

As indicated in the table below, second quarter 2020 weighted average realized price (including transportation) was $1.65 per Mcfe including derivatives, down 24% from $2.17 per Mcfe in the prior year period. Settled derivatives provided a $0.60 per Mcfe uplift to realized price, but were more than offset by lower commodity prices, including a 35% decrease to NYMEX Henry Hub and 53% decrease in West Texas Intermediate (WTI), compared to prior year.

During the second quarter, the Company realized $120 million in cash settled derivative gains, bringing year-to-date cash settled derivative gains to $213 million. As of June 30, 2020, the fair value of unsettled derivatives for the remainder of 2020 was a $195 million asset. The Company has 385 Bcfe of its remaining expected 2020 production hedged with swaps and collars for approximately 90% of natural gas, 95% of oil and 60% of NGLs. In addition, the Company has 145 Bcf of natural gas financial basis hedges.

As of June 30, 2020, Southwestern Energy had total debt of $2.46 billion and a cash balance of $10 million, with a leverage ratio of 3.1x. During the quarter, the Company reduced senior notes by $27 million through open market repurchases at a 24% discount, bringing year-to-date senior notes reduction to $107 million, at a 33% discount. The Company's senior notes totaled $2.12 billion, with only $207 million due before 2025.

At the end of the second quarter, the Company had $1.26 billion undrawn commitment under its $1.8 billion revolving credit facility with $336 million borrowed and $209 million in outstanding letters of credit. Since April, the Company was able to convert $113 million in outstanding letters of credit to surety bonds.

Realized Prices For the three months For the six months ended ended

(includes June 30, June 30,transportation costs)

2020 2019 2020 2019

Natural Gas Price:

NYMEX Henry Hub price $ 1.72 $ 2.64 $ 1.83 $ 2.89 ($/MMBtu) ^(1)

Discount to NYMEX ^(2) (0.74 ) (0.84 ) (0.57 ) (0.52 )

Realized gas price perMcf, excluding $ 0.98 $ 1.80 $ 1.26 $ 2.37 derivatives

Gain (loss) on settledfinancial basis (0.05 ) (0.03 ) 0.03 (0.03 ) derivatives ($/Mcf)

Gain on settled 0.57 0.17 0.43 0.04 commodity derivatives

Realized gas price perMcf, including $ 1.50 $ 1.94 $ 1.72 $ 2.38 derivatives

Oil Price, per Bbl:

WTI oil price $ 27.85 $ 59.81 $ 37.01 $ 57.36

Discount to WTI (12.16 ) (10.26 ) (9.46 ) (9.75 )

Realized oil price, $ 15.69 $ 49.55 $ 27.55 $ 47.61 excluding derivatives

Realized oil price, $ 41.64 $ 51.60 $ 44.08 $ 49.80 including derivatives

NGL Price, per Bbl:

Realized NGL price, $ 6.43 $ 10.51 $ 7.29 $ 12.50 excluding derivatives

Realized NGL price, $ 8.22 $ 12.62 $ 9.50 $ 13.84 including derivatives

Percentage of WTI, 23 % 18 % 20 % 22 %excluding derivatives

Total Weighted Average Realized Price:

Excluding derivatives $ 1.05 $ 1.99 $ 1.37 $ 2.48 ($/Mcfe)

Including derivatives $ 1.65 $ 2.17 $ 1.90 $ 2.54 ($/Mcfe)

(1) Based on last day monthly futures settlement prices.

This discount includes a basis differential, a heating content adjustment,(2) physical basis sales, third-party transportation charges and fuel charges, and excludes financial basis derivatives

Operational Results

Total production for the quarter ended June 30, 2020 was 201 Bcfe, comprised of 79% natural gas, 18% NGLs and 3% oil. Capital investments totaled $245 million for the second quarter, with 30 wells drilled, 31 wells completed and 31 wells placed to sales. During the quarter, the Company shifted activity to high-rate, high-volume natural gas wells, with over 80% of wells drilled in dry gas Northeast Appalachia and rich gas Southwest Appalachia. The Company has revised its well count guidance ranges to reflect the shift in activity, with full year capital investment estimated to be split evenly between Northeast Appalachia and Southwest Appalachia.

The Company continues to deliver well cost reductions ahead of expectations. In the second quarter, wells to sales averaged $691 per lateral foot, with an expected full year average of $690 per foot, compared to original guidance of $730 per foot. This incremental reduction is due to operational efficiencies, completion design optimization and deflationary service costs. Additionally, the Company expects to average $650 per foot for wells to sales in the second half of 2020.

For the three months For the six months ended ended

June 30, June 30,

2020 2019 2020 2019

Production

Gas production (Bcf) 158 148 314 291

Oil production (MBbls) 1,083 937 2,482 1,791

NGL production (MBbls) 6,111 5,497 12,239 11,100

Total production (Bcfe) 201 186 402 368



Average unit costs per Mcfe

Lease operating expenses $ 0.91 $ 0.90 $ 0.94 $ 0.90

General & administrative $ 0.14 $ 0.19 $ 0.13 $ 0.19 expenses ^(1)

Taxes, other than income taxes $ 0.05 $ 0.09 $ 0.06 $ 0.10

Full cost pool amortization $ 0.38 $ 0.55 $ 0.46 $ 0.56

Excludes restructuring charges (including severance) of $2 million for the(1) three months ended June 30, 2020 and 2019, and $12 million and $5 million for the six months ended June 30, 2020 and 2019, respectively.

Southwest Appalachia - In the second quarter, total production was 88 Bcfe, half of which was liquids production of 79 MBbls per day. The Company drilled nine wells, completed 17 wells and placed 20 wells to sales. The average lateral length of wells to sales was 11,469 feet, and included six wells in the rich area and 14 wells in the super rich area. All six of the rich wells were online for at least 30 days and had an average 30-day rate of 17.2 MMcfe per day, while 12 of the super rich wells were online for at least 30 days and had an average 30-day rate of 7.3 MMcfe per day, including 67% liquids. The production rates associated with the super rich wells were temporarily managed lower to mitigate condensate market constraints that existed early in the second quarter.

Northeast Appalachia - Second quarter production was 113 Bcf. There were 21 wells drilled, 14 wells completed and 11 wells put to sales with an average lateral length of 9,693 feet. Of the eight wells that were online for at least 30 days, six were Lower Marcellus, with an average 30-day rate of 14.8 MMcf per day. Second quarter wells to sales represented a different well mix compared to the first quarter, which was primarily located in the higher rate Tioga area. The two remaining wells were part of the Upper Marcellus testing and had an average 30-day rate of 8.3 MMcf per day.

E&P Division Results For the three months For the six months ended June 30, 2020 ended June 30, 2020

Northeast Southwest Northeast Southwest

Gas production (Bcf) 113 45 227 87

Liquids production

Oil (MBbls) - 1,079 - 2,474

NGL (MBbls) - 6,110 - 12,237

Production (Bcfe) 113 88 227 175



Gross operated production 1,475 1,569 June 2020 (MMcfe/d)

Net operated production 1,203 973 June 2020 (MMcfe/d)



Capital investments ($ in millions)

Drilling and completions, $ 107 $ 87 $ 186 $ 197 including workovers

Land acquisition and 4 7 5 13 other

Capitalized interest and 4 29 10 59 expense

Total capital investments $ 115 $ 123 $ 201 $ 269



Gross operated well activity summary

Drilled 21 9 36 32

Completed 14 17 24 29

Wells to sales 11 20 16 27



Average well cost onwells to sales (in $ 6.2 $ 8.2 $ 6.6 $ 8.9 millions)

Average lateral length 9,693 11,469 9,475 11,981 (in ft)



Total weighted averagerealized price per Mcfe, $ 1.03 $ 1.08 $ 1.37 $ 1.37 excluding derivatives

Updated Guidance

The Company revised its annual guidance to reflect lower costs across all categories and higher NGL price realizations as a percentage of WTI. Production guidance is also revised due to the shift in activity to high-rate, high-volume gas, resulting in a rebalance of production mix and well count. Updated guidance noted in bold:

1st 2nd 3rd 4th Quarter Quarter Quarter Quarter Total Year Actual Actual

Production

Natural Gas (Bcf) 156 158 170 - 177 177 - 184 661 - 675

Oil/Condensate 1,399 1,083 1,300 - 1,275 - 5,057 -(MBbls) 1,400 1,375 5,257

NGLs (MBbls) 6,128 6,111 6,350 - 6,750 - 25,339 - 6,625 7,025 25,889

Total Production 201 201 216 - 225 225 - 234 843 - 861(Bcfe)

Total Production 2,213 2,203 2,347 - 2,446 - 2,303 -(MMcfe/d) 2,446 2,543 2,352

CAPITAL BY DIVISION (in millions)

Northeast Appalachia $330 - $345

Southwest Appalachia $365 - $380

Other $25 - $30

Capitalized interest $85 - $95

Capitalized expense $55 - $65

Total Capital Investments $860 - $915

PRODUCTION BY DIVISION (Bcfe)

Northeast Appalachia 471 - 480

Southwest Appalachia 372 - 381



PRICING

Natural gas discount to NYMEX including transportation $0.63 - $0.73 per Mcf

Oil discount to West Texas Intermediate (WTI) including $9.50 - $11.50 pertransportation Bbl

Natural Gas Liquids realization as a % of WTI including 19% - 24%transportation



EXPENSES

Lease operating expenses $0.90 - $0.94 per Mcfe

General & administrative expense $0.11 - $0.15 per Mcfe

Taxes, other than income taxes $0.05 - $0.07 per Mcfe



Interest expense - net of capitalization $78 - $88 MM

Income tax rate (~100% deferred) 23.5%

WELL COUNTS

Drilled Completed Wells To Sales Ending DUC Inventory

Northeast Appalachia 45 - 50 40 - 45 40 - 45 5 - 10

Southwest Appalachia 45 - 50 50 - 55 50 - 55 15 - 20

Total Well Count 90 - 100 90 - 100 90 - 100 20 - 30

Conference Call

Southwestern Energy will host a conference call on Friday, July 31, 2020 at 9:30 a.m. Central to discuss second quarter 2020 results. To participate, dial US toll-free 877-883-0383, or international 412-902-6506 and enter access code 6529300. A live webcast will be available at ir.swn.com and a replay will be archived following the call.

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 10145880. The replay will be available until August 31, 2020.

About Southwestern Energy

Southwestern Energy Company is an independent energy company engaged in natural gas, natural gas liquids and oil exploration, development, production and marketing. For additional information, visit 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," "model," "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, natural gas liquids and oil reserves or production; impact of reduced demand for our products and products made from them due to governmental and societal actions taken in response to the COVID-19 pandemic; operating hazards, drilling risks, unsuccessful exploratory activities; natural disasters and epidemics; 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; the risks related to the discontinuation of LIBOR and/or other reference rates that may be introduced following the transition, including increased expenses and litigation and the effectiveness of interest rate hedge strategies; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; failure or delay in obtaining necessary regulatory approvals; potential liability resulting from pending or future litigation; general domestic and international economic and political conditions, including the impact of COVID-19; the impact of a prolonged federal, state or local government shutdown and threats not to increase the federal government's debt limit; 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

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)



For the three months ended For the six months ended

June 30, June 30,

(in millions,except share/ 2020 2019 2020 2019per shareamounts)

Operating Revenues:

Gas sales $ 164 $ 275 $ 412 $ 705

Oil sales 19 47 71 86

NGL sales 40 58 90 139

Marketing 187 287 426 725

Other - - 3 2

410 667 1,002 1,657

OperatingCosts and Expenses:

Marketing 201 293 449 734 purchases

Operating 182 169 375 334 expenses

General andadministrative 32 40 58 77 expenses

Loss on saleof operating - 3 - 3 assets

Restructuring 2 2 12 5 charges

Depreciation,depletion and 84 115 197 227 amortization

Impairments 655 6 2,134 6

Taxes, otherthan income 10 17 23 36 taxes

1,166 645 3,248 1,422

Operating (756 ) 22 (2,246 ) 235 Income (Loss)

Interest Expense:

Interest on 40 41 80 83 debt

Other interest 3 2 5 3 charges

Interest (21 ) (28 ) (44 ) (57 ) capitalized

22 15 41 29



Gain (Loss) on (109 ) 152 230 120 Derivatives

Gain on EarlyExtinguishment 7 - 35 - of Debt

Other Income - (6 ) 1 (5 ) (Loss), Net



Income (Loss)Before Income (880 ) 153 (2,021 ) 321 Taxes

Provision(Benefit) for Income Taxes

Current - - (2 ) -

Deferred - 15 408 (411 )

- 15 406 (411 )

Net Income $ (880 ) $ 138 $ (2,427 ) $ 732 (Loss)



Earnings(Loss) Per Common Share

Basic $ (1.63 ) $ 0.26 $ (4.49 ) $ 1.36

Diluted $ (1.63 ) $ 0.26 $ (4.49 ) $ 1.35



WeightedAverage Common SharesOutstanding:

Basic 541,079,192 539,005,941 540,693,841 539,362,984

Diluted 541,079,192 539,947,053 540,693,841 540,624,742

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

June 30, December 2020 31, 2019

ASSETS (in millions)

Current assets:

Cash and cash equivalents $ 10 $ 5

Accounts receivable, net 250 345

Derivative assets 466 278

Other current assets 44 51

Total current assets 770 679

Natural gas and oil properties, using the full costmethod, including $1,423 million as of June 30, 2020 25,739 25,250 and $1,506 million as of December 31, 2019 excludedfrom amortization

Other 512 520

Less: Accumulated depreciation, depletion and (22,825 ) (20,503 )amortization

Total property and equipment, net 3,426 5,267

Operating lease assets 153 159

Deferred tax assets - 407

Other long-term assets 206 205

Total long-term assets 359 771

TOTAL ASSETS $ 4,555 $ 6,717

LIABILITIES AND EQUITY

Current liabilities:

Accounts payable $ 426 $ 525

Taxes payable 48 59

Interest payable 48 51

Derivative liabilities 282 125

Current operating lease liabilities 34 34

Other current liabilities 37 54

Total current liabilities 875 848

Long-term debt 2,440 2,242

Long-term operating lease liabilities 113 119

Pension and other postretirement liabilities 37 43

Other long-term liabilities 267 219

Total long-term liabilities 2,857 2,623

Commitments and contingencies

Equity:

Common stock, $0.01 par value; 1,250,000,000 sharesauthorized; issued 586,593,540 shares as of June 30, 6 6 2020 and 585,555,923 shares as of December 31, 2019

Additional paid-in capital 4,730 4,726

Accumulated deficit (3,678 ) (1,251 )

Accumulated other comprehensive loss (33 ) (33 )

Common stock in treasury, 44,353,224 shares as of June (202 ) (202 )30, 2020 and December 31, 2019

Total equity 823 3,246

TOTAL LIABILITIES AND EQUITY $ 4,555 $ 6,717



SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

For the six months ended

June 30,

(in millions) 2020 2019

Cash Flows From Operating Activities:

Net income (loss) $ (2,427 ) $ 732

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

Depreciation, depletion and amortization 197 227

Amortization of debt issuance costs 4 2

Impairments 2,134 6

Deferred income taxes 408 (411 )

Gain on derivatives, unsettled (17 ) (96 )

Stock-based compensation 2 4

Gain on early extinguishment of debt (35 ) -

Loss on sale of assets - 3

Other - 10

Change in assets and liabilities:

Accounts receivable 94 221

Accounts payable (121 ) (129 )

Taxes payable (11 ) (6 )

Interest payable (1 ) 1

Inventories 6 4

Other assets and liabilities 21 (25 )

Net cash provided by operating activities 254 543



Cash Flows From Investing Activities:

Capital investments (472 ) (586 )

Proceeds from sale of property and equipment 2 26

Net cash used in investing activities (470 ) (560 )



Cash Flows From Financing Activities:

Payments on long-term debt (72 ) -

Payments on revolving credit facility (919 ) -

Borrowings under revolving credit facility 1,221 -

Change in bank drafts outstanding (8 ) (7 )

Purchase of treasury stock - (21 )

Cash paid for tax withholding (1 ) (1 )

Net cash provided by (used in) financing activities 221 (29 )



Increase (decrease) in cash and cash equivalents 5 (46 )

Cash and cash equivalents at beginning of year 5 201

Cash and cash equivalents at end of period $ 10 $ 155

Hedging Summary

A detailed breakdown of derivative financial instruments and financial basis positions as of June 30, 2020, including the remainder of 2020 and excluding those positions that settled in the first and second quarters, 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 Swaps Sold Purchased Sold (Bcf) Puts Puts Calls

Natural gas

2020

Fixed price swaps 218 $ 2.39 $ - $ - $ -

Two-way costless 44 - - 2.12 2.34collars

Three-way costless 59 - 2.18 2.57 2.96collars

Total 321

2021

Fixed price swaps 36 $ 2.53 $ - $ - $ -

Two-way costless 55 - - 2.34 2.76collars

Three-way costless 306 - 2.16 2.49 2.85collars

Total 397

2022

Two-way costless 29 $ - $ - $ 2.10 $ 2.83collars

Three-way costless 99 - 2.08 2.45 2.85collars

Total 128

2023

Three-way costless 9 $ - $ 2.16 $ 2.59 $ 3.36collars

Weighted Average Price per Bbl

Volume Swaps Sold Purchased Sold (MBbls) Puts Puts Calls

Oil

2020

Fixed price swaps ^(1) 1,107 $ 72.54 $ - $ - $ -

Two-way costless 502 - - 56.83 59.78collars

Three-way costless 895 - 43.54 52.57 57.55collars

Total 2,504

2021

Fixed price swaps 2,328 $ 53.72 $ - $ - $ -

Three-way costless 1,445 - 43.52 53.25 58.14collars

Total 3,773

2022

Fixed price swaps 438 $ 51.74 $ - $ - $ -

Three-way costless 666 - 42.50 53.20 58.00collars

Total 1,104

Ethane

2020

Fixed price swaps 5,230 $ 8.61 $ - $ - $ -

2021

Fixed price swaps 5,889 $ 7.12 $ - $ - $ -

2022

Fixed price swaps 136 $ 7.35 $ - $ - $ -

Propane

2020

Fixed price swaps 2,748 $ 23.01 $ - $ - $ -

Two-way costless 184 - - 25.20 29.40collars

Total 2,932

2021

Fixed price swaps 4,298 $ 19.99 $ - $ - $ -

2022

Fixed price swaps 105 $ 19.43 $ - $ - $ -

(1) Includes 790 MBbls of purchased fixed price oil swaps at $36.64 per barrel and 1,897 MBbls of sold fixed price oil swaps at $57.60 per barrel.

Natural gas financial basis positions Volume Basis Differential

(Bcf) ($/MMBtu)

Q3 2020

Dominion South 41 $ (0.53 )

TCO 18 $ (0.46 )

TETCO M3 22 $ (0.42 )

Total 81 $ (0.48 )

Q4 2020

Dominion South 35 $ (0.51 )

TCO 11 $ (0.43 )

TETCO M3 18 $ (0.10 )

Total 64 $ (0.38 )

2021

Dominion South 71 $ (0.47 )

TCO 22 $ (0.36 )

TETCO M3 57 $ 0.36

Total 150 $ (0.14 )

2022

Dominion South 69 $ (0.51 )

TCO 17 $ (0.37 )

TETCO M3 36 $ (0.41 )

Total 122 $ (0.46 )

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 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.

3 Months Ended June 6 Months Ended June 30, 30,

2020 2019 2020 2019

Adjusted net income (loss): (in millions)

Net income (loss) $ (880 ) $ 138 $ (2,427 ) $ 732

Add back (deduct):

Restructuring charges 2 2 12 5

Impairments 655 6 2,134 6

Loss on sale of assets - 3 - 3

(Gain) loss on derivatives, 229 (118 ) (17 ) (96 )unsettled

Gain on early extinguishment of (7 ) - (35 ) - debt

Non-cash pension settlement loss - 4 - 4

Other (gain) loss (1 ) 3 (1 ) 1

Adjustments due to discrete tax 207 (23 ) 881 (489 )items ^(1)

Tax impact on adjustments (206 ) 25 (492 ) 19

Adjusted net income (loss) $ (1 ) $ 40 $ 55 $ 185

2020 primarily relates to the recognition of a valuation allowance. 2019(1) primarily relates to the release of the valuation allowance. The Company expects its 2020 income tax rate to be 23.5% before the impacts of any valuation allowance.

3 Months Ended June 6 Months Ended June 30, 30,

2020 2019 2020 2019

Adjusted diluted earnings (loss) per share:

Diluted earnings (loss) per share $ (1.63 ) $ 0.26 $ (4.49 ) $ 1.35

Add back (deduct):

Restructuring charges 0.01 0.00 0.02 0.01

Impairments 1.21 0.01 3.95 0.01

Loss on sale of assets - 0.00 - 0.01

(Gain) loss on derivatives, 0.42 (0.22 ) (0.03 ) (0.18 )unsettled

Gain on early extinguishment of (0.01 ) - (0.07 ) - debt

Non-cash pension settlement loss - 0.01 - 0.01

Other (gain) loss (0.00 ) 0.01 (0.00 ) 0.00

Adjustments due to discrete tax 0.38 (0.04 ) 1.63 (0.91 )items ^(1)

Tax impact on adjustments (0.38 ) 0.05 (0.91 ) 0.04

Adjusted diluted earnings (loss) $ (0.00 ) $ 0.08 $ 0.10 $ 0.34 per share

2020 primarily relates to the recognition of a valuation allowance. 2019 primarily relates to the release of the valuation allowance. The Company(1) expects its 2020 income tax rate to be 23.5% before the impacts of any valuation allowance.

3 Months Ended June 6 Months Ended June 30, 30,

2020 2019 2020 2019

Net cash flow: (in millions)

Net cash provided by operating $ 94 $ 101 $ 254 $ 543 activities

Add back (deduct):

Changes in operating assets and (9 ) 70 12 (66 )liabilities

Restructuring charges 2 2 12 5

Net cash flow $ 87 $ 173 $ 278 $ 482

3 Months Ended June 6 Months Ended June 30, 30,

2020 2019 2020 2019

Adjusted EBITDA: (in millions)

Net income (loss) $ (880 ) $ 138 $ (2,427 ) $ 732

Add back (deduct):

Interest expense 22 15 41 29

Provision (benefit) for income - 15 406 (411 )taxes

Depreciation, depletion and 84 115 197 227 amortization

Restructuring charges 2 2 12 5

Impairments 655 6 2,134 6

Loss on sale of assets - 3 - 3

(Gain) loss on derivatives, 229 (118 ) (17 ) (96 )unsettled

Gain on early extinguishment of (7 ) - (35 ) - debt

Non-cash pension settlement loss - 4 - 4

Other (gain) loss - 4 (1 ) 2

Stock-based compensation expense 1 2 2 4

Adjusted EBITDA $ 106 $ 186 $ 312 $ 505

June 30, 2020

Net debt: (in millions)

Total debt ^(1) $ 2,457

Subtract:

Cash and cash equivalents (10 )

Net debt $ 2,447

Does not include $17 million of unamortized debt discount and issuance(1) expense.

June 30, 2020

Net debt to EBITDA: (in millions)

Net debt $ 2,447

Adjusted EBITDA ^(1) $ 780

Net debt to EBITDA 3.1x

(1) Adjusted EBITDA for the twelve months ended June 30, 2020.

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