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SOUTHWESTERN ENERGY ANNOUNCES THIRD QUARTER 2019 RESULTS
Transition plan back to free cash flow neutral by year end 2020 remains on track; resilience bolstered by leading operational efficiency, increasing condensate yield and extended financial strength and flexibility
SPRING, Texas – October 24, 2019...Southwestern Energy Company (NYSE: SWN)
today announced financial and operating results for the third quarter ended September 30, 2019.
•Leading operational efficiency gains expected to result in full-year wells to sales at the high end of guidance while not exceeding $1.15 billion annual capital investment;
•Beating 25% reduction target for full-year average well costs, averaging $784 per lateral foot and 10,466 feet lateral length in the quarter;
•Condensate production of greater than 15 MBbls per day, up 50% from second quarter, contributing 19% of E&P revenues;
•Total production of 202 Bcfe, including 22% liquids at approximately 80 MBbls per day;
•Borrowing
base reaffirmed, revolver maturity extended one year to 2024, no borrowings outstanding under $2 billion commitment as of September 30, 2019;
•Realized $88 million of settled derivative gains, increasing weighted average realized price by $0.44 per Mcfe; and
•Reported weighted average realized price of $2.55 per Mcfe, including derivatives and excluding transportation.
“The SWN team continues to innovate and deliver value, embracing the challenges our industry faces today. Our people are driving improved operational efficiency and cost structure, maximizing cash flow, increasing well performance and optimizing base production,” said Southwestern Energy President and Chief Executive Officer, Bill Way.
“In
this volatile commodity environment, resiliency is key today and going forward. The intentional actions we have taken over time and continue to take to strengthen our balance sheet, coupled with operational execution, are all a part of our deliberate transition back to free cash flow, without compromising long-term value. We are in an enviable position with our debt maturity profile to take advantage of financial, operational and strategic opportunities,” Way continued.
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 nine months ended
September 30,
September 30,
(in millions)
2019
2018
2019
2018
Net
income (loss) attributable to common stock
$
49
$
(29)
$
781
$
229
Adjusted net income attributable to common stock (non-GAAP)
$
44
$
146
$
229
$
414
Diluted
earnings (loss) per share
$
0.09
$
(0.05)
$
1.44
$
0.39
Adjusted diluted earnings per share (non-GAAP)
$
0.08
$
0.25
$
0.42
$
0.71
Adjusted
EBITDA (non-GAAP)
$
202
$
377
(1)
$
707
$
1,090
(1)
Net cash provided by operating activities
$
196
$
307
$
739
$
971
Net
cash flow (non-GAAP)
$
185
$
355
$
667
$
993
Total capital investments (2)
$
240
$
298
$
933
$
1,039
(1)Includes
$99 million and $291 million of Adjusted EBITDA from the divested Fayetteville Shale assets for the three and nine months ended September 30, 2018, respectively.
(2)Capital investments on the cash flow statement include decreases of $53 million and $31 million for the three months ended September 30, 2019 and 2018, respectively, and increases of $52 million and $21 million for the nine months ended September 30, 2019 and 2018, respectively, relating to the change in accrued expenditures between periods.
Southwestern Energy reported net income attributable to common stock of
$49 million, or $0.09 per share, and adjusted net income (non-GAAP) of $44 million, or $0.08 per share. The decrease in adjusted net income as compared to the third quarter of 2018 is primarily due to decreased commodity prices, partially offset by an $88 million increase in the gain from settled derivatives. Adjusted EBITDA (non-GAAP) was $202 million, net cash provided by operating activities was $196 million and net cash flow (non-GAAP) was $185 million.
In the third quarter, the Company benefited $0.44 per Mcfe from the impact of settled commodity derivatives, reporting a weighted average realized price of $2.16 per Mcfe, essentially the same as in the second quarter, even with the lower commodity price environment. Excluding $0.39 per Mcfe in transportation costs, weighted average realized price for the third quarter
was $2.55 per Mcfe. The Company benefited from its rolling three-year hedging program, continued focus on condensate production and optimizing its low-cost transportation portfolio.
By commodity, including the benefit of derivatives, SWN's realized natural gas price was $1.87 per Mcf, oil realizations were $49.67 per Bbl and NGL realizations were $11.93 per Bbl. Excluding derivatives, the natural gas differential to NYMEX was $0.78 per Mcf, oil differential to WTI was $9.91 per Bbl and NGL realizations were 16% of WTI. All realized prices include the cost of transportation.
The Company added derivatives for 2020 during the quarter, bringing the total financial
derivative volumes for next year to 360 Bcf of natural gas, 2,837 MBbls of oil and 7,137 MBbls of NGLs. Of the natural gas volumes hedged in 2020, over half are protected by collars, which limits exposure to the downside risk while allowing for upside. The 2020 natural gas three-way collars have an average floor price of $2.67 per MMBtu, a ceiling price of $2.98 per MMBtu and a sub-floor price of $2.34 per MMBtu. Fixed price swaps comprise 42% of 2020 natural gas hedges with an average strike price of $2.58 per MMBtu and settlement dates primarily in the second and third quarters.
2
At September 30, 2019, the Company had cash of
$29 million, an undrawn revolver of $2 billion, total debt of $2.3 billion and a trailing 12 month net debt/EBITDA ratio of 2.2 times, excluding the benefit of Adjusted EBITDA associated with the Fayetteville Shale. During the quarter, the Company repurchased $50 million of senior notes at a discount of 13%, which will reduce interest costs on senior notes by $21 million until maturity. These repurchases were funded principally by sales of non-core, non-producing assets.
In accordance with its planned activity reduction, Southwestern Energy invested capital totaling $240 million, including capitalized interest and expense of $45 million, bringing year to date capital investment to $933 million. As announced earlier this year, annual capital investment is not expected to exceed $1.15 billion.
Loss
on settled financial basis derivatives ($/Mcf)
(0.01)
(0.03)
(0.02)
(0.04)
Gain on settled commodity derivatives ($/Mcf)
0.43
0.05
0.18
0.07
Realized
gas price per Mcf, including derivatives
$
1.87
$
2.16
$
2.20
$
2.31
Oil Price:
WTI
oil price ($/Bbl)
$
56.45
$
69.50
$
57.06
$
66.75
Discount to WTI
(9.91)
(8.30)
(9.92)
(7.24)
Realized
oil price per Bbl, excluding derivatives
$
46.54
$
61.20
$
47.14
$
59.51
Realized oil price per Bbl, including derivatives
$
49.67
$
59.96
$
49.74
$
58.69
NGL
Price:
Realized NGL price per Bbl, excluding derivatives
$
8.89
$
21.60
$
11.24
$
17.65
Realized
NGL price per Bbl, including derivatives
$
11.93
$
19.43
$
13.18
$
16.75
Percentage of WTI
16
%
31
%
20
%
26
%
Total
Weighted Average Realized Price:
Excluding derivatives ($/Mcfe)
$
1.72
$
2.51
$
2.21
$
2.51
Including
derivatives ($/Mcfe)
$
2.16
$
2.48
$
2.41
$
2.51
(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 202 Bcfe, an 8% increase compared to the prior year third quarter excluding Fayetteville, including 158 Bcf of gas production, 1.4 MMBbls of oil production and 5.9 MMBbls of NGL production. Oil production was up 42% compared to the third quarter of 2018 and liquids increased to 22% of total production for the quarter ended September 30, 2019.
Capital invested was on plan at $240 million, 35% lower than the second quarter. During the third quarter, SWN drilled 24 wells, completed 30 wells and placed 34 wells to sales. The average well cost for wells to
sales in the third quarter of 2019 was $784 per lateral foot, with an average lateral length of 10,466 feet. In the first nine months of 2019, the
3
Company drilled 95 wells, completed 101 wells and placed 89 wells to sales, with well costs for wells to sales averaging $849 per lateral foot.
Gross operated production as of September 2019 (MMcfe/d)
1,553
1,707
Net
operated production as of September 2019 (MMcfe/d)
1,258
1,059
Capital investments ($ in millions)
Exploratory
and development drilling, including workovers
$
65
$
109
Acquisition and leasehold
—
9
Seismic
and other
1
—
Capitalized interest and expense
8
36
Total capital investments
$
74
$
154
Gross
operated well activity summary
Drilled
10
14
Completed
14
16
Wells
to sales
13
21
Average well cost on wells to sales (in millions)
$
6.5
$
9.2
Average
lateral length (in ft)
8,739
11,534
Total
weighted average realized price per Mcfe, excluding derivatives
$
1.49
$
2.04
Southwest Appalachia’s total production averaged 913 MMcfe per day, which represents a 27% growth over the prior year quarter. Natural gas production was 440 MMcf per day, oil production was 15.4 MBbls per day and natural gas liquids production was 64.2 MBbls per day. Similar to the previous quarter, natural gas liquids volumes were reduced to capture
greater value through ethane rejection into the gas stream.
The Company drilled 14 wells, completed 16 wells and placed 21 wells to sales in the quarter. Of the 21 wells to sales, 20 were Marcellus wells, 16 located in the Company’s super rich acreage and four located in the rich acreage. The Company also brought online its fourth Upper Devonian well, its first located in the super rich acreage, with initial standalone performance in line with offset Marcellus wells in the area.
Nine of the super rich wells were online for at least 30 days and had an average 30-day rate of 13 MMcfe per
day, while the four rich wells were all online for at least 30 days and had an average 30-day rate of 27 MMcfe per day, representing a 60% and 100% increase year over year, respectively, primarily driven by lateral length and well performance.
Northeast Appalachia’s total production averaged 1.3 Bcf per day, essentially flat with prior year quarter.
4
During the third quarter, the Company drilled 10 wells, completed 14 wells and placed 13 wells to sales. Of the nine wells online for at least 30 days, six were Lower Marcellus with an average 30-day rate of 15 MMcf per day, 14% higher than
the prior year quarter. Three of the nine were new generation Upper Marcellus tests with an average 30-day rate of 10 MMcf per day, in line with expectations.
As a part of its ongoing base optimization efforts, the Company began to see the benefit of recently installed pad compression resulting in an initial gross production uplift of 55 MMcf per day. These continued efforts are reducing the base decline and can be applied across a broader area.
(2)LOE
includes post-production costs such as: gathering, processing, fractionation and compression charges.
(3)Excludes restructuring charges.
(4)Excludes a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building and $3 million of legal settlement charges for the three and nine months ended September 30, 2019.
(5)Excludes $8 million of legal settlement charges for the nine months ended September 30, 2018.
(6)Excludes $1 million on restructuring charges for the nine months ended September 30, 2018.
Conference
Call
Southwestern Energy will host a conference call and webcast on October 25, 2019 at 9:30 a.m. Central Time to discuss third quarter 2019 financial and operating results. To participate, dial US toll-free 877-883-0383, or international 412-902-6506 and enter access code 2888599. The conference call will be webcast live at www.swn.com/investors/.
A replay of the call will be available until November 15, 2019
at 877-344-7529, International 412-317-0088, or Canada Toll Free 855-669-9658, access code 10135186.
5
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 websitewww.swn.com.
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.
Natural
gas and oil properties, using the full cost method, including $1,518 million as of September 30, 2019 and $1,755 million as of December 31, 2018 excluded from amortization
25,060
24,180
Other
522
525
Less:
Accumulated depreciation, depletion and amortization
(20,383)
(20,049)
Total property and equipment, net
5,199
4,656
Deferred tax assets
398
—
Other
long-term assets
368
185
TOTAL ASSETS
$
6,598
$
5,797
LIABILITIES AND EQUITY
Current liabilities:
Current
portion of long-term debt
$
52
$
—
Accounts payable
539
609
Taxes payable
55
58
Interest
payable
57
52
Derivative liabilities
85
79
Other current liabilities
92
48
Total
current liabilities
880
846
Long-term debt
2,219
2,318
Pension and other postretirement liabilities
39
46
Other
long-term liabilities
325
225
Total long-term liabilities
2,583
2,589
Commitments and contingencies
Equity:
Common
stock, $0.01 par value; 1,250,000,000 shares authorized; issued 585,637,420 shares as of September 30, 2019 and 585,407,107 shares as of December 31, 2018
Adjustments
to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization
352
426
Amortization of debt issuance costs
5
6
Impairments
8
171
Deferred
income taxes
(400)
—
(Gain) loss on derivatives, unsettled
(108)
113
Stock-based compensation
6
12
(Gain)
loss on early extinguishment of debt
(7)
8
Loss on sale of assets, net
3
—
Other
11
7
Change
in assets and liabilities:
Accounts receivable
257
(7)
Accounts payable
(124)
60
Taxes payable
(3)
—
Interest
payable
2
(5)
Inventories
(2)
(9)
Other assets and liabilities
(42)
(41)
Net
cash provided by operating activities
739
971
Cash Flows From Investing Activities:
Capital investments
(877)
(1,008)
Proceeds
from sale of property and equipment
42
9
Other
—
4
Net cash used in investing activities
(835)
(995)
Cash
Flows From Financing Activities:
Payments on long-term debt
(43)
(1,191)
Payments on revolving credit facility
—
(1,122)
Borrowings
under revolving credit facility
—
1,482
Change in bank drafts outstanding
(11)
10
Debt issuance costs
—
(9)
Purchase
of treasury stock
(21)
(25)
Preferred stock dividend
—
(27)
Cash paid for tax withholding
(1)
(1)
Net
cash used in financing activities
(76)
(883)
Decrease in cash and cash equivalents
(172)
(907)
Cash and cash equivalents at beginning of year
201
916
Cash
and cash equivalents at end of period
$
29
$
9
9
Hedging Summary
A detailed breakdown of Southwestern Energy’s derivative financial instruments and financial basis positions as of September 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
61
$
2.89
$
—
$
—
$
—
$
—
Two-way
costless collars
6
—
—
2.78
2.92
—
Three-way costless collars
44
—
2.43
2.82
3.15
—
Total
111
2020
Fixed
price swaps
151
$
2.58
$
—
$
—
$
—
$
—
Three-way
costless collars
209
—
2.34
2.67
2.98
—
Total
360
2021
Three-way
costless collars
134
$
—
$
2.27
$
2.55
$
2.85
$
—
2022
Three-way
costless collars
23
$
—
$
2.30
$
2.70
$
3.14
$
—
Basis
Swaps
2019
35
$
—
$
—
$
—
$
—
$
(0.40)
2020
141
—
—
—
—
(0.31)
2021
65
—
—
—
—
(0.48)
2022
45
—
—
—
—
(0.50)
Total
286
10
Weighted
Average Price per Bbl
Volume
Sold
Purchased
Sold
(MBbls)
Swaps
Puts
Puts
Calls
Oil
2019
Fixed
price swaps (1)
632
$
60.65
$
—
$
—
$
—
Two-way costless collars
382
—
—
61.45
67.16
Three-way
costless collars
138
—
45.00
55.00
63.67
Total
1,152
2020
Fixed
price swaps
1,556
$
60.18
$
—
$
—
$
—
Two-way costless collars
366
—
—
60.00
69.80
Three-way
costless collars
915
—
45.00
55.00
61.75
Total
2,837
2021
Three-way
costless collars
730
$
—
$
45.00
$
53.00
$
59.50
Propane
2019
Fixed
price swaps
978
$
30.18
$
—
$
—
$
—
Two-way costless collars
138
—
—
25.62
28.77
Total
1,116
2020
Fixed
price swaps
2,928
$
25.58
$
—
$
—
$
—
Two-way costless collars
366
—
—
25.20
29.40
Total
3,294
2021
Fixed
price swaps
456
$
22.24
$
—
$
—
$
—
Ethane
2019
Fixed
price swaps
2,194
$
10.53
$
—
$
—
$
—
2020
Fixed
price swaps
3,843
$
9.80
$
—
$
—
$
—
(1)Includes 69 MBbls of purchased fixed price oil swaps hedged at $69.10 per barrel and 701 MBbls of sold fixed price oil swaps
hedged at $61.48 per barrel.
11
Financial basis positions
Volume
Basis Differential
(excludes physical positions)
(Bcf)
($/MMBtu)
Q4
2019
TCO
1
$
(0.38)
Dominion South
21
$
(0.54)
TETCO M3
13
$
(0.17)
Total
35
$
(0.40)
2020
TCO
17
$
(0.51)
Dominion
South
80
$
(0.52)
TETCO M3
42
$
0.07
Transco Z6 NonNY
2
$
2.02
Total
141
$
(0.31)
2021
Dominion
South
61
$
(0.48)
TETCO M3
4
$
(0.40)
Total
65
$
(0.48)
2022
Dominion
South
36
$
(0.52)
TETCO M3
9
$
(0.45)
Total
45
$
(0.50)
12
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.
(1)Includes a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building for the
three and nine months ended September 30, 2019.
(2)2019 primarily relates to the release of the valuation allowance. 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%.
(1)Includes a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building for the three and nine months ended September
30, 2019.
(2)2019 primarily relates to the release of the valuation allowance. 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%.
(1)Includes
a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building for the three and nine months ended September 30, 2019.
(1)Includes
a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building for the three and nine months ended September 30, 2019.
(1)Includes Adjusted EBITDA of $1,102 million for the twelve months ended September
30, 2019, less $87 million of EBITDA generated by Fayetteville E&P and Midstream prior to the December 2018 divestiture.
15
Dates Referenced Herein and Documents Incorporated by Reference
