August 6, 2019 - 4:30 PM EDT
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Southwestern Energy Announces Second Quarter 2019 Results

SPRING, Texas

Ongoing capital efficiencies driving top end of capital guidance lower; planned second half activity reduction underway

Southwestern Energy Company (NYSE: SWN) today announced financial and operating results for the quarter ended June 30, 2019.

“SWN’s position as a leading Appalachia producer is underpinned by its operational outperformance, continued cost reduction, disciplined capital allocation and prudent commodity management. This, combined with a strong balance sheet and no material near term debt maturities, provides resilience in this volatile commodity price environment,” said Bill Way, President and Chief Executive Officer, Southwestern Energy.

  • Planned second half activity reduction underway with average rig count reduced from 6 rigs in the first half to 2 rigs by the end of the third quarter;
  • Invested total capital of $368 million, consistent with front-half loaded capital program;
  • On track to deliver 25% annual average well cost reduction on wells to sales; $866 per lateral foot in the quarter with average lateral length of over 10,100 feet;
  • Lowered top end of capital guidance, not to exceed $1.15 billion due to ongoing capital efficiency improvements;
  • Reported Appalachia production of 186 Bcfe, up 11% compared to prior year quarter; liquids production of 70.7 MBbls per day, 21% of production;
  • Captured $2.61 per Mcfe weighted average realized price, including derivatives and excluding $0.44 per Mcfe of transportation costs, essentially flat compared to prior year quarter;
  • Net debt to EBITDA of 2.0 times excluding the benefit of 2018 Fayetteville EBITDA; undrawn revolver of $2 billion; no material debt maturities before 2025;
  • 72% of projected gas production hedged for the remainder of the year with a fair value of gas derivitives of $110 million at June 30, 2019; and
  • Improved gas differentials and LOE costs expected to more than offset lower NGL realizations by approximately $40 million for the year; updated guidance follows.

 

 

Previous Annual Guidance

 

Updated Annual Guidance

Lease operating expense

 

$0.92 - $0.97 per Mcfe

 

$0.90 - $0.94 per Mcfe

Natural gas differentials

 

$0.70 - $0.80 per Mcf

 

$0.60 - $0.70 per Mcf

NGL price realizations

 

24% - 29% of WTI

 

18% - 22% of WTI

“We reiterate our priority of returning to free cash flow by the end of 2020, which remains achievable at recent strip prices. This strategic objective will be enabled by our continuing operational and cost improvements, without compromising our demonstrated operating and financial discipline, including our practice of investing within a fully funded capital program,” continued Way.

Financial Results

The table below summarizes financial statistics. Year over year results are not comparable as prior year’s results include the contribution of Fayetteville assets, which were sold in December 2018.

FINANCIAL STATISTICS

 

For the three months ended

 

For the six months ended

 

 

June 30,

 

June 30,

(in millions)

 

2019

 

2018

 

2019

 

2018

Net income attributable to common stock

 

$

138

 

$

51

 

$

732

 

$

257

Adjusted net income attributable to common stock (non-GAAP)

 

$

40

 

$

105

 

$

185

 

$

267

Adjusted EBITDA (non-GAAP)

 

$

186

 

$

317

 

$

505

 

$

713

Net cash provided by operating activities

 

$

101

 

$

300

 

$

543

 

$

664

Net cash flow (non-GAAP)

 

$

173

 

$

280

 

$

482

 

$

638

Total capital investments (1)

 

$

368

 

$

403

 

$

693

 

$

741

(1) Capital investments on the cash flow statement include increases of $39 million and $19 million for the three months ended June 30, 2019 and 2018, respectively, and increases of $105 million and $52 million for the six months ended June 30, 2019 and 2018, respectively, relating to the change in accrued expenditures between periods.

Southwestern Energy reported net income attributable to common stock of $138 million, or $0.26 per share, and adjusted net income of $40 million, or $0.08 per share. Compared to the prior year quarter these results include interest expense savings of $17 million and general and administrative expense savings of $19 million. Adjusted EBITDA was $186 million, net cash provided by operating activities was $101 million and net cash flow (non-GAAP) was $173 million.

Weighted average realized price was $2.17 per Mcfe, which includes transportation costs and the benefit of $0.18 per Mcfe from settled derivatives. By commodity, including the benefit of derivatives, realized gas price was $1.94 per Mcf, oil realizations were $51.60 per Bbl and NGL realizations were $12.62 per Bbl.

Excluding derivatives, which is consistent with guidance, natural gas differential was $0.84 per Mcf, NGL realizations were 18% of WTI and oil differential was $10.26 per Bbl.

For the second half of 2019, 72% of the Company’s natural gas production, 34% of NGLs and 77% of oil are hedged, based on the midpoint of guidance.

At June 30, 2019, the Company had cash of $155 million, an undrawn revolver of $2 billion, total debt of $2.3 billion and a trailing 12 month net debt/EBITDA ratio of 2.0 times, excluding the benefit of EBITDA associated with the Fayetteville Shale.

During the quarter, Southwestern Energy invested capital totaling $368 million, including capitalized interest and expense of $46 million, bringing year to date capital investment to $693 million, consistent with the Company’s previously disclosed front-half weighted capital program. Further, as planned, the Company has already begun to manage down capital investment with average rig count reduced from 6 rigs in the first half to 2 rigs by the end of the third quarter. Total capital investment for the year is not expected to exceed $1.15 billion, below the high end of original capital guidance, and the Company reaffirms original annual production guidance.

REALIZED PRICES

 

For the three months ended

 

For the six months ended

(includes transportation costs)

 

June 30,

 

June 30,

 

 

2019

 

2018

 

2019

 

2018

Natural Gas Price:

 

 

 

 

 

 

 

 

NYMEX Henry Hub price ($/MMBtu) (1)

 

$

2.64

 

 

$

2.80

 

 

$

2.89

 

 

$

2.90

 

Discount to NYMEX (2)

 

(0.84

)

 

(0.81

)

 

(0.52

)

 

(0.55

)

Realized gas price per Mcf, excluding derivatives

 

$

1.80

 

 

$

1.99

 

 

$

2.37

 

 

$

2.35

 

Loss on settled financial basis derivatives ($/Mcf)

 

(0.03

)

 

(0.01

)

 

(0.03

)

 

(0.06

)

Gain on settled commodity derivatives ($/Mcf)

 

0.17

 

 

0.13

 

 

0.04

 

 

0.10

 

Realized gas price per Mcf, including derivatives

 

$

1.94

 

 

$

2.11

 

 

$

2.38

 

 

$

2.39

 

Oil Price:

 

 

 

 

 

 

 

 

WTI oil price ($/Bbl)

 

$

59.81

 

 

$

67.88

 

 

$

57.36

 

 

$

65.37

 

Discount to WTI

 

(10.26

)

 

(7.73

)

 

(9.75

)

 

(7.12

)

Realized oil price per Bbl, excluding derivatives

 

$

49.55

 

 

$

60.15

 

 

$

47.61

 

 

$

58.25

 

Realized oil price per Bbl, including derivatives

 

$

51.60

 

 

$

59.22

 

 

$

49.80

 

 

$

57.74

 

NGL Price:

 

 

 

 

 

 

 

 

Realized NGL price per Bbl, excluding derivatives

 

$

10.51

 

 

$

15.37

 

 

$

12.50

 

 

$

15.39

 

Realized NGL price per Bbl, including derivatives

 

$

12.62

 

 

$

15.05

 

 

$

13.84

 

 

$

15.22

 

Percentage of WTI

 

18

%

 

23

%

 

22

%

 

24

%

Realized C3+ price per Bbl, excluding derivatives

 

$

20.91

 

 

$

33.11

 

 

$

23.85

 

 

$

34.49

 

Realized C3+ price per Bbl, including derivatives

 

$

23.68

 

 

$

32.32

 

 

$

25.73

 

 

$

34.07

 

Percentage of WTI

 

35

%

 

49

%

 

42

%

 

53

%

Total Weighted Average Realized Price:

 

 

 

 

 

 

 

 

Excluding derivatives ($/Mcfe)

 

$

1.99

 

 

$

2.21

 

 

$

2.48

 

 

$

2.51

 

Including derivatives ($/Mcfe)

 

$

2.17

 

 

$

2.30

 

 

$

2.54

 

 

$

2.53

 

(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.

Operational Results
Total production was 186 Bcfe, an 11% increase compared to the prior-year second quarter excluding Fayetteville, including 148 Bcf of gas production, 937 MBbls of oil production and 5,497 MBbls of natural gas liquids production. E&P capital invested was $349 million, 8% lower than the second quarter of 2018. During the quarter, SWN drilled 41 wells, completed 40 wells and placed 36 wells to sales.

Well Cost Update
The Company is on track to achieve its commitment of averaging $875 per lateral foot for all wells to sales in 2019. This quarter, the Company achieved an average well cost of $866 per lateral foot with an average completed lateral length of 10,128 feet. Average well costs per lateral foot includes title, regulatory, permitting, pad site, facilities, drilling, completion and initial flowback costs. Longer lateral lengths, piped water, self-sourced sand and operational outperformance are the primary contributors to improving well costs.

  • Lateral length on wells to sales increased 30% year over year
  • Realizing an average savings of approximately $800,000 per well for all wells utilizing Southwest Appalachia water infrastructure; 100% of wells completed this year will utilize piped water
  • Sand savings of $230,000 per well have exceeded original estimates
  • Stages per day expected to improve 35% in 2019 to 7.2 stages per day, compared to full year 2018

Three Months Ended June 30, 2019 E&P Division Results

 

Appalachia

 

 

Northeast

 

Southwest

Gas Production (Bcf)

 

113

 

35

Liquids Production

 

 

 

 

Oil (MBbls)

 

 

931

NGL (MBbls)

 

 

5,493

Production (Bcfe)

 

113

 

73

Gross operated production as of June 2019 (MMcfe/d)

 

1,487

 

1,367

Net operated production as of June 2019 (MMcfe/d)

 

1,212

 

847

 

 

 

 

 

Capital investments ($ in millions)

 

 

 

 

Exploratory and development drilling, including workovers

 

$

115

 

$

169

Acquisition and leasehold

 

1

 

15

Seismic and other

 

2

 

1

Capitalized interest and expense

 

8

 

38

Total capital investments

 

$

126

 

$

223

 

 

 

 

 

Gross operated well activity summary

 

 

 

 

Drilled

 

18

 

23

Completed

 

14

 

26

Wells to sales

 

13

 

23

 

 

 

 

 

Average well cost on wells to sales (in millions)

 

$

8.5

 

$

8.9

Average lateral length (in ft)

 

9,981

 

10,211

 

 

 

 

 

Total weighted average realized price per Mcfe, excluding derivatives

 

$

1.91

 

$

2.10

Southwest Appalachia’s total production averaged 802 MMcfe per day, including 10.2 MBbls per day of oil and 60.4 MBbls per day of natural gas liquids. During the quarter, natural gas liquids production was reduced to capture greater value through ethane rejection. The Company drilled 23 wells, completed 26 wells and placed 23 wells to sales in the quarter. In alignment with the Company’s plan to focus on liquids-rich Marcellus wells, all 23 wells brought online this quarter were located in the super rich acreage and had an average lateral length of 10,211 feet.

Twelve of the 23 wells were online for at least 30 days and had an average 30-day rate of 11 MMcfe per day, an over 60% increase compared to second quarter last year. The improvement is attributed to longer lateral lengths and well performance improvements.

Northeast Appalachia’s total production averaged 1.2 Bcf per day, essentially flat to the prior year quarter. In the quarter, the Company drilled 18 wells, completed 14 wells and placed 13 wells to sales with an average lateral length of 9,981 feet.

Wells to sales in the quarter had an average initial production rate of 25 MMcf per day, 25% higher than the same quarter last year, driven predominantly by longer lateral lengths. Four of the 13 wells to sales in the quarter were online for at least 30 days and had an average 30-day rate of 17 MMcf per day.

OPERATING STATISTICS

 

For the three months ended

 

For the six months ended

 

 

 

June 30,

 

June 30,

 

 

 

2019

 

2018

 

2019

 

2018

 

Production

 

 

 

 

 

 

 

 

 

Gas production (Bcf)

 

148

 

201

 

291

 

398

 

Oil production (MBbls)

 

937

 

723

 

1,791

 

1,336

 

NGL production (MBbls)

 

5,497

 

4,862

 

11,100

 

9,092

 

Total production (Bcfe)

 

186

 

234

 

368

 

460

 

 

 

 

 

 

 

 

 

 

 

Division Production

 

 

 

 

 

 

 

 

 

Northeast Appalachia (Bcf)

 

113

 

112

 

225

 

220

 

Southwest Appalachia (Bcfe)

 

73

 

55

 

143

 

106

 

Fayetteville Shale (Bcf) (1)

 

 

67

 

 

134

 

 

 

 

 

 

 

 

 

 

 

Average unit costs per Mcfe

 

 

 

 

 

 

 

 

 

Lease operating expenses (2)

 

$

0.90

 

$

0.91

 

$

0.90

 

$

0.93

 

General & administrative expenses

 

$

0.19

(3)

$

0.19

(4)

$

0.19

(3)

$

0.20

(4)

Taxes, other than income taxes

 

$

0.09

 

$

0.06

(5)

$

0.10

 

$

0.07

(5)

Full cost pool amortization

 

$

0.58

 

$

0.50

 

$

0.57

 

$

0.49

 

(1) The Fayetteville Shale assets were sold on December 3, 2018.
(2) LOE includes post-production costs such as: gathering, processing, fractionation and compression charges.
(3) Excludes $2 million and $5 million of restructuring charges for the three and six months ended June 30, 2019, respectively.
(4) Excludes $15 million of restructuring charges and $7.9 million of legal settlement charges for the three and six months ended June 30, 2018.
(5) Excludes $1 million of restructuring charges for the three and six months ended June 30, 2018.

Resource to Reserves
The Company continued its testing program in the quarter by successfully drilling and completing three Upper Marcellus wells and completing its first Upper Devonian well in the super rich acreage. All four wells are expected to be online in the third quarter.

Conference Call
Southwestern Energy will host a conference call and webcast on August 7, 2019 at 9:30 a.m. Central Time to discuss second quarter 2019 financial and operating results. To participate, dial US toll-free 877-883-0383, or international 412-902-6506 and enter access code 1226688. The conference call will be webcast live at www.swn.com/investors/.

A replay of the call will be available until August 28, 2019 at 877-344-7529, International 412-317-0088, or Canada Toll Free 855-669-9658, access code 10133404.

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,” “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; 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; 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; 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/per share amounts)

 

2019

 

2018

 

2019

 

2018

Operating Revenues:

 

 

 

 

 

 

 

 

Gas sales

 

$

275

 

 

$

407

 

 

$

705

 

 

$

947

 

Oil sales

 

47

 

 

44

 

 

86

 

 

79

 

NGL sales

 

58

 

 

75

 

 

139

 

 

140

 

Marketing

 

287

 

 

265

 

 

725

 

 

518

 

Gas gathering

 

 

 

24

 

 

 

 

48

 

Other

 

 

 

1

 

 

2

 

 

4

 

 

 

667

 

 

816

 

 

1,657

 

 

1,736

 

Operating Costs and Expenses:

 

 

 

 

 

 

 

 

Marketing purchases

 

293

 

 

265

 

 

734

 

 

520

 

Operating expenses

 

169

 

 

193

 

 

334

 

 

382

 

General and administrative expenses

 

40

 

 

59

 

 

77

 

 

114

 

Loss on sale of operating assets

 

3

 

 

 

 

3

 

 

 

Restructuring charges

 

2

 

 

18

 

 

5

 

 

18

 

Depreciation, depletion and amortization

 

121

 

 

142

 

 

233

 

 

285

 

Taxes, other than income taxes

 

17

 

 

15

 

 

36

 

 

38

 

 

 

645

 

 

692

 

 

1,422

 

 

1,357

 

Operating Income

 

22

 

 

124

 

 

235

 

 

379

 

Interest Expense:

 

 

 

 

 

 

 

 

Interest on debt

 

41

 

 

59

 

 

83

 

 

124

 

Other interest charges

 

2

 

 

2

 

 

3

 

 

4

 

Interest capitalized

 

(28

)

 

(29

)

 

(57

)

 

(57

)

 

 

15

 

 

32

 

 

29

 

 

71

 

 

 

 

 

 

 

 

 

 

Gain (Loss) on Derivatives

 

152

 

 

(36

)

 

120

 

 

(43

)

Loss on Early Extinguishment of Debt

 

 

 

(8

)

 

 

 

(8

)

Other Income (Loss), Net

 

(6

)

 

3

 

 

(5

)

 

2

 

 

 

 

 

 

 

 

 

 

Income Before Income Taxes

 

153

 

 

51

 

 

321

 

 

259

 

Provision (Benefit) for Income Taxes:

 

 

 

 

 

 

 

 

Current

 

 

 

 

 

 

 

 

Deferred

 

15

 

 

 

 

(411

)

 

 

 

 

15

 

 

 

 

(411

)

 

 

Net Income

 

$

138

 

 

$

51

 

 

$

732

 

 

$

259

 

Participating securities - mandatory convertible preferred stock

 

 

 

 

 

 

 

2

 

Net Income Attributable to Common Stock

 

$

138

 

 

$

51

 

 

$

732

 

 

$

257

 

 

 

 

 

 

 

 

 

 

Earnings Per Common Share

 

 

 

 

 

 

 

 

Basic

 

$

0.26

 

 

$

0.09

 

 

$

1.36

 

 

$

0.45

 

Diluted

 

$

0.26

 

 

$

0.09

 

 

$

1.35

 

 

$

0.44

 

 

 

 

 

 

 

 

 

 

Weighted Average Common Shares Outstanding:

 

 

 

 

 

 

 

 

Basic

 

539,005,941

 

 

581,159,200

 

 

539,362,984

 

 

576,255,744

 

Diluted

 

539,947,053

 

 

582,878,106

 

 

540,624,742

 

 

578,222,740

 

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

 

 

June 30,
2019

 

December 31,
2018

ASSETS

 

(in millions)

Current assets:

 

 

 

 

Cash and cash equivalents

 

$

155

 

 

$

201

 

Accounts receivable, net

 

358

 

 

581

 

Derivative assets

 

209

 

 

130

 

Other current assets

 

42

 

 

44

 

Total current assets

 

764

 

 

956

 

Natural gas and oil properties, using the full cost method, including $1,678 million as of June 30, 2019 and $1,755 million as of December 31, 2018 excluded from amortization

 

24,823

 

 

24,180

 

Other

 

555

 

 

525

 

Less: Accumulated depreciation, depletion and amortization

 

(20,279

)

 

(20,049

)

Total property and equipment, net

 

5,099

 

 

4,656

 

Deferred tax assets

 

410

 

 

 

Other long-term assets

 

272

 

 

185

 

TOTAL ASSETS

 

$

6,545

 

 

$

5,797

 

LIABILITIES AND EQUITY

 

 

 

 

Current liabilities:

 

 

 

 

Current portion of long-term debt

 

$

52

 

 

$

 

Accounts payable

 

585

 

 

609

 

Taxes payable

 

52

 

 

58

 

Interest payable

 

53

 

 

52

 

Derivative liabilities

 

67

 

 

79

 

Other current liabilities

 

103

 

 

48

 

Total current liabilities

 

912

 

 

846

 

Long-term debt

 

2,267

 

 

2,318

 

Pension and other postretirement liabilities

 

39

 

 

46

 

Other long-term liabilities

 

245

 

 

225

 

Total long-term liabilities

 

2,551

 

 

2,589

 

Commitments and contingencies

 

 

 

 

Equity:

 

 

 

 

Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 585,478,345 shares as of June 30, 2019 and 585,407,107 shares as of December 31, 2018

 

6

 

 

6

 

Additional paid-in capital

 

4,720

 

 

4,715

 

Accumulated deficit

 

(1,410

)

 

(2,142

)

Accumulated other comprehensive loss

 

(32

)

 

(36

)

Common stock in treasury, 44,353,224 shares as of June 30, 2019 and 39,092,537 shares as of December 31, 2018

 

(202

)

 

(181

)

Total equity

 

3,082

 

 

2,362

 

TOTAL LIABILITIES AND EQUITY

 

$

6,545

 

 

$

5,797

 

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

 

 

For the six months ended

 

 

June 30,

(in millions)

 

2019

 

2018

Cash Flows From Operating Activities:

 

 

 

 

Net income

 

$

732

 

 

$

259

 

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

Depreciation, depletion and amortization

 

233

 

 

285

 

Amortization of debt issuance costs

 

2

 

 

4

 

Deferred income taxes

 

(411

)

 

 

(Gain) loss on derivatives, unsettled

 

(96

)

 

54

 

Stock-based compensation

 

4

 

 

9

 

Loss on early extinguishment of debt

 

 

 

8

 

Loss on sale of assets, net

 

3

 

 

 

Other

 

10

 

 

1

 

Change in assets and liabilities

 

 

 

 

 

 

Accounts receivable

 

221

 

 

12

 

Accounts payable

 

(129

)

 

53

 

Taxes payable

 

(6

)

 

(4

)

Interest payable

 

1

 

 

(1

)

Inventories

 

4

 

 

(7

)

Other assets and liabilities

 

(25

)

 

(9

)

Net cash provided by operating activities

 

543

 

 

664

 

 

 

 

 

 

Cash Flows From Investing Activities:

 

 

 

 

Capital investments

 

(586

)

 

(684

)

Proceeds from sale of property and equipment

 

26

 

 

6

 

Other

 

 

 

3

 

Net cash used in investing activities

 

(560

)

 

(675

)

 

 

 

 

 

Cash Flows From Financing Activities:

 

 

 

 

Payments on long-term debt

 

 

 

(1,191

)

Payments on revolving credit facility

 

 

 

(645

)

Borrowings under revolving credit facility

 

 

 

1,005

 

Change in bank drafts outstanding

 

(7

)

 

 

Debt issuance costs

 

 

 

(9

)

Purchase of treasury stock

 

(21

)

 

 

Preferred stock dividend

 

 

 

(27

)

Cash paid for tax withholding

 

(1

)

 

(1

)

Net cash used in financing activities

 

(29

)

 

(868

)

 

 

 

 

 

Decrease in cash and cash equivalents

 

(46

)

 

(879

)

Cash and cash equivalents at beginning of year

 

201

 

 

916

 

Cash and cash equivalents at end of period

 

$

155

 

 

$

37

 

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES

SEGMENT INFORMATION

(Unaudited)

 

 

Exploration

 

 

 

 

 

 

 

 

 

 

and

 

Midstream

 

 

 

 

 

 

 

 

Production

 

Services

 

Other

 

Eliminations

 

Total

 

 

(in millions)

Three months ended June 30, 2019

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

371

 

 

$

626

 

 

$

 

 

$

(330

)

 

$

667

 

Marketing purchases

 

 

 

622

 

 

 

 

(329

)

 

293

 

Operating expenses

 

169

 

 

1

 

 

 

 

(1

)

 

169

 

General and administrative expenses

 

35

 

 

5

 

 

 

 

 

 

40

 

Loss on sale of operating assets

 

 

 

3

 

 

 

 

 

 

3

 

Restructuring charges

 

2

 

 

 

 

 

 

 

 

2

 

Depreciation, depletion and amortization

 

118

 

 

3

 

 

 

 

 

 

121

 

Taxes, other than income taxes

 

17

 

 

 

 

 

 

 

 

17

 

Operating income (loss)

 

30

 

 

(8

)

 

 

 

 

 

22

 

Capital investments (1)

 

367

 

 

 

 

1

 

 

 

 

368

 

 

 

 

 

 

 

 

 

 

 

 

Three months ended June 30, 2018

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

520

 

 

$

797

 

 

$

 

 

$

(501

)

 

$

816

 

Marketing purchases

 

 

 

716

 

 

 

 

(451

)

 

265

 

Operating expenses

 

215

 

 

28

 

 

 

 

(50

)

 

193

 

General and administrative expenses

 

53

 

(2)

6

 

 

 

 

 

 

59

 

Restructuring charges

 

16

 

 

2

 

 

 

 

 

 

18

 

Depreciation, depletion and amortization

 

126

 

 

16

 

(3)

 

 

 

 

142

 

Taxes, other than income taxes

 

13

 

 

2

 

 

 

 

 

 

15

 

Operating income

 

97

 

 

27

 

 

 

 

 

 

124

 

Capital investments (1)

 

396

 

 

5

 

 

2

 

 

 

 

403

 

 

 

 

 

 

 

 

 

 

 

 

Six months ended June 30, 2019

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

913

 

 

$

1,567

 

 

$

 

 

$

(823

)

 

$

1,657

 

Marketing purchases

 

 

 

1,556

 

 

 

 

(822

)

 

734

 

Operating expenses

 

335

 

 

 

 

 

 

(1

)

 

334

 

General and administrative expenses

 

69

 

 

8

 

 

 

 

 

 

77

 

Loss on sale of operating assets

 

 

 

3

 

 

 

 

 

 

3

 

Restructuring charges

 

5

 

 

 

 

 

 

 

 

5

 

Depreciation, depletion and amortization

 

228

 

 

5

 

 

 

 

 

 

233

 

Taxes, other than income taxes

 

36

 

 

 

 

 

 

 

 

36

 

Operating income (loss)

 

240

 

 

(5

)

 

 

 

 

 

235

 

Capital investments (1)

 

692

 

 

 

 

1

 

 

 

 

693

 

 

 

 

 

 

 

 

 

 

 

 

Six months ended June 30, 2018

 

 

 

 

 

 

 

 

 

 

Revenues

 

$

1,157

 

 

$

1,693

 

 

$

 

 

$

(1,114

)

 

$

1,736

 

Marketing purchases

 

 

 

1,535

 

 

 

 

(1,015

)

 

520

 

Operating expenses

 

428

 

 

53

 

 

 

 

(99

)

 

382

 

General and administrative expenses

 

101

 

(2)

13

 

 

 

 

 

 

114

 

Restructuring charges

 

16

 

 

2

 

 

 

 

 

 

18

 

Depreciation, depletion and amortization

 

243

 

 

42

 

(3)

 

 

 

 

285

 

Taxes, other than income taxes

 

34

 

 

4

 

 

 

 

 

 

38

 

Operating income

 

335

 

 

44

 

 

 

 

 

 

379

 

Capital investments (1)

 

730

 

 

9

 

 

2

 

 

 

 

741

 

(1) Capital investments include increases of $39 million and $19 million for the three months ended June 30, 2019 and 2018, respectively, and increases of $105 million and $52 million for the six months ended June 30, 2019 and 2018, respectively, relating to the change in accrued expenditures between years.
(2) Includes $7.9 million of legal settlement charges.
(3) Includes a $10 million impairment related to certain non-core gathering assets.

Hedging Summary
A detailed breakdown of Southwestern Energy’s derivative financial instruments and financial basis positions as of June 30, 2019 is shown below. Please refer to the quarterly report on Form 10-Q 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

 

 

 

Sold

 

Purchased

 

Sold

 

Basis

 

(Bcf)

 

Swaps

 

Puts

 

Puts

 

Calls

 

Differential

Natural Gas

 

 

 

 

 

 

 

 

 

 

 

2019

 

 

 

 

 

 

 

 

 

 

 

Fixed price swaps

131

 

 

$

2.92

 

 

$

 

 

$

 

 

$

 

 

$

 

Two-way costless collars

25

 

 

 

 

 

 

2.78

 

 

2.92

 

 

 

Three-way costless collars

67

 

 

 

 

2.47

 

 

2.88

 

 

3.22

 

 

 

Total

223

 

 

 

 

 

 

 

 

 

 

 

2020

 

 

 

 

 

 

 

 

 

 

 

Fixed price swaps

24

 

 

$

2.88

 

 

$

 

 

$

 

 

$

 

 

$

 

Three-way costless collars

148

 

 

 

 

2.36

 

 

2.67

 

 

2.97

 

 

 

Total

172

 

 

 

 

 

 

 

 

 

 

 

2021

 

 

 

 

 

 

 

 

 

 

 

Three-way costless collars

37

 

 

$

 

 

$

2.35

 

 

$

2.60

 

 

$

2.93

 

 

$

 

 

 

 

 

 

 

 

 

 

 

 

 

Basis Swaps

 

 

 

 

 

 

 

 

 

 

 

2019

80

 

 

$

 

 

$

 

 

$

 

 

$

 

 

$

(0.45

)

2020

132

 

 

 

 

 

 

 

 

 

 

(0.34

)

2021

28

 

 

 

 

 

 

 

 

 

 

(0.51

)

Total

240

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted Average Price per Bbl

 

Volume

 

 

 

Sold

 

Purchased

 

Sold

 

(MBbls)

 

Swaps

 

Puts

 

Puts

 

Calls

Oil

 

 

 

 

 

 

 

 

 

2019

 

 

 

 

 

 

 

 

 

Fixed price swaps (1)

1,003

 

 

$

60.89

 

 

$

 

 

$

 

 

$

 

Two-way costless collars

764

 

 

 

 

 

 

61.45

 

 

67.16

 

Three-way costless collars

276

 

 

 

 

45.00

 

 

55.00

 

 

63.67

 

Total

2,043

 

 

 

 

 

 

 

 

 

2020

 

 

 

 

 

 

 

 

 

Fixed price swaps

1,556

 

 

$

60.18

 

 

$

 

 

$

 

 

$

 

Two-way costless collars

366

 

 

 

 

 

 

60.00

 

 

69.80

 

Three-way costless collars

641

 

 

 

 

45.00

 

 

55.00

 

 

63.36

 

Total

2,563

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Propane

 

 

 

 

 

 

 

 

 

2019

 

 

 

 

 

 

 

 

 

Fixed price swaps

1,955

 

 

$

30.18

 

 

$

 

 

$

 

 

$

 

Two-way costless collars

276

 

 

 

 

 

 

25.62

 

 

28.77

 

Total

2,231

 

 

 

 

 

 

 

 

 

2020

 

 

 

 

 

 

 

 

 

Fixed price swaps

2,196

 

 

$

26.97

 

 

$

 

 

$

 

 

$

 

Two-way costless collars

366

 

 

 

 

 

 

25.20

 

 

29.40

 

Total

2,562

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Ethane

 

 

 

 

 

 

 

 

 

2019

 

 

 

 

 

 

 

 

 

Fixed price swaps

1,858

 

 

$

13.90

 

 

$

 

 

$

 

 

$

 

2020

 

 

 

 

 

 

 

 

 

Fixed price swaps

732

 

 

$

13.49

 

 

$

 

 

$

 

 

$

 

(1) Includes 138 MBbls of purchased fixed price oil swaps hedged at $69.10 per barrel and 1,141 MBbls of sold fixed price oil swaps hedged at $61.88 per barrel.

Financial basis positions

 

Volume

 

Basis Differential

(excludes physical positions)

 

(Bcf)

 

($/MMbtu)

 

 

 

 

 

Q3 2019

 

 

 

 

TCO

 

2

 

$

(0.38

)

Dominion South

 

30

 

$

(0.53

)

TETCO M3

 

14

 

$

(0.43

)

Total

 

46

 

$

(0.49

)

 

 

 

 

 

2019

 

 

 

 

TCO

 

2

 

$

(0.38

)

Dominion South

 

51

 

$

(0.53

)

TETCO M3

 

27

 

$

(0.30

)

Total

 

80

 

$

(0.45

)

 

 

 

 

 

2020

 

 

 

 

TCO

 

17

 

$

(0.51

)

Dominion South

 

80

 

$

(0.52

)

TETCO M3

 

35

 

$

0.16

 

Total

 

132

 

$

(0.34

)

 

 

 

 

 

2021

 

 

 

 

Dominion South

 

24

 

$

(0.53

)

TETCO M3

 

4

 

$

(0.40

)

Total

 

28

 

$

(0.51

)

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 30,

 

 

2019

 

2018

 

 

(in millions)

Net income attributable to common stock:

 

 

 

 

Net income attributable to common stock

 

$

138

 

 

$

51

 

Add back:

 

 

 

 

Restructuring charges

 

2

 

 

18

 

Loss on sale of operating assets

 

3

 

 

 

(Gain) loss on certain derivatives

 

(118

)

 

56

 

Loss on early extinguishment of debt

 

 

 

8

 

Legal settlement charges

 

 

 

8

 

Non-cash pension settlement loss

 

4

 

 

 

Other non-cash (gain) loss

 

9

 

 

(1

)

Adjustments due to discrete tax items (1)

 

(23

)

 

(13

)

Tax impact on adjustments

 

25

 

 

(22

)

Adjusted net income attributable to common stock

 

$

40

 

 

$

105

 

(1) 2018 primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2019 income tax rate to be 24.5%.

 

 

6 Months Ended June 30,

 

 

2019

 

2018

 

 

(in millions)

Net income attributable to common stock:

 

 

 

 

Net income attributable to common stock

 

$

732

 

 

$

257

 

Add back:

 

 

 

 

Restructuring charges

 

5

 

 

18

 

Loss on sale of operating assets

 

3

 

 

 

(Gain) loss on certain derivatives

 

(96

)

 

54

 

Impairment of non-core gathering assets

 

 

 

10

 

Loss on early extinguishment of debt

 

 

 

8

 

Legal settlement charge

 

 

 

8

 

Non-cash pension settlement loss

 

4

 

 

 

Other non-cash loss

 

7

 

 

1

 

Adjustments due to discrete tax items (1)

 

(489

)

 

(64

)

Tax impact on adjustments

 

19

 

 

(25

)

Adjusted net income attributable to common stock

 

$

185

 

 

$

267

 

(1) 2018 primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2019 income tax rate to be 24.5%.

 

 

3 Months Ended June 30,

 

 

2019

 

2018

Diluted earnings per share:

 

 

 

 

Diluted earnings per share

 

$

0.26

 

 

$

0.09

 

Add back:

 

 

 

 

Restructuring charges

 

0.00

 

 

0.03

 

Loss on sale of operating assets

 

0.00

 

 

 

(Gain) loss on certain derivatives

 

(0.22

)

 

0.10

 

Loss on early extinguishment of debt

 

 

 

0.01

 

Legal settlement charges

 

 

 

0.01

 

Non-cash pension settlement loss

 

0.01

 

 

 

Other non-cash (gain) loss

 

0.02

 

 

(0.00

)

Adjustments due to discrete tax items (1)

 

(0.04

)

 

(0.02

)

Tax impact on adjustments

 

0.05

 

 

(0.04

)

Adjusted diluted earnings per share

 

$

0.08

 

 

$

0.18

 

(1) 2018 primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2019 income tax rate to be 24.5%.

 

 

6 Months Ended June 30,

 

 

2019

 

2018

Diluted earnings per share:

 

 

 

 

Diluted earnings per share

 

$

1.35

 

 

$

0.44

 

Add back:

 

 

 

 

Restructuring charges

 

0.01

 

 

0.03

 

Loss on sale of operating assets

 

0.01

 

 

 

(Gain) loss on certain derivatives

 

(0.18

)

 

0.09

 

Impairment of non-core gathering assets

 

 

 

0.02

 

Loss on early extinguishment of debt

 

 

 

0.02

 

Legal settlement charges

 

 

 

0.01

 

Non-cash pension settlement loss

 

0.01

 

 

 

Other non-cash loss

 

0.01

 

 

0.00

 

Adjustments due to discrete tax items (1)

 

(0.91

)

 

(0.11

)

Tax impact on adjustments

 

0.04

 

 

(0.04

)

Adjusted diluted earnings per share

 

$

0.34

 

 

$

0.46

 

(1) 2018 primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2019 income tax rate to be 24.5%.

 

 

3 Months Ended June 30,

 

 

2019

 

2018

 

 

(in millions)

Net cash flow provided by operating activities:

 

 

 

 

Net cash provided by operating activities

 

$

101

 

 

$

300

 

Add back:

 

 

 

 

Changes in operating assets and liabilities

 

70

 

 

(38

)

Restructuring charges

 

2

 

 

18

 

Net cash flow

 

$

173

 

 

$

280

 

 

 

 

6 Months Ended June 30,

 

 

2019

 

2018

 

 

(in millions)

Net cash flow provided by operating activities:

 

 

 

 

Net cash provided by operating activities

 

$

543

 

 

$

664

 

Add back:

 

 

 

 

Changes in operating assets and liabilities

 

(66

)

 

(44

)

Restructuring charges

 

5

 

 

18

 

Net cash flow

 

$

482

 

 

$

638

 

 

 

3 Months Ended June 30,

 

 

2019

 

2018

 

 

(in millions)

 

EBITDA:

 

 

 

 

 

Net income

 

$

138

 

 

$

51

 

Add back:

 

 

 

 

 

Interest expense

 

15

 

 

32

 

Income tax expense

 

15

 

 

 

Depreciation, depletion and amortization

 

116

 

 

142

 

Restructuring charges

 

2

 

 

18

 

Loss on sale of operating assets

 

3

 

 

 

(Gain) loss on certain derivatives

 

(118

)

 

56

 

Loss on early extinguishment of debt

 

 

 

8

 

Legal settlement charges

 

 

 

8

 

Non-cash pension settlement loss

 

4

 

 

 

Other non-cash (gain) loss

 

9

 

 

(1

)

Stock based compensation expense

 

2

 

 

3

 

Adjusted EBITDA

 

$

186

 

 

$

317

 

   

 

 

6 Months Ended June 30,

 

 

2019

 

2018

 

 

(in millions)

 

EBITDA:

 

 

 

 

 

Net income

 

$

732

 

 

$

259

 

Add back:

 

 

 

 

 

Interest expense

 

29

 

 

71

 

Income tax benefit

 

(411

)

 

 

Depreciation, depletion and amortization

 

228

 

 

285

 

Restructuring charges

 

5

 

 

18

 

Loss on sale of operating assets

 

3

 

 

 

(Gain) loss on certain derivatives

 

(96

)

 

54

 

Loss on early extinguishment of debt

 

 

 

8

 

Legal settlement charges

 

 

 

8

 

Non-cash pension settlement loss

 

4

 

 

 

Other non-cash loss

 

7

 

 

1

 

Stock based compensation expense

 

4

 

 

9

 

Adjusted EBITDA

 

$

505

 

 

$

713

 

       

 

   

 

June 30, 2019

 

   

 

(in millions)

Total debt:

   

 

$

2,319

 

Subtract:

   

 

 

 

Cash and cash equivalents

   

 

(155

)

Net debt

   

 

$

2,164

 

       

 

   

 

June 30, 2019

 

   

 

(in millions)

Net debt:

   

 

$

2,164

 

Adjusted EBITDA (1)

   

 

$

1,090

 

Net debt to EBITDA

   

 

2.0x

 

(1) Includes Adjusted EBITDA of $1,276 million for the twelve months ended June 30, 2019 less $186 million of EBITDA generated by Fayetteville E&P and Midstream prior to the December 2018 divestiture.

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Investor Contact
Paige Penchas
Vice President, Investor Relations
(832) 796-4068
[email protected]

Media Contact
Jim Schwartz
Director, Corporate Communications
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Source: Business Wire (August 6, 2019 - 4:30 PM EDT)

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