Project: Rover Pipeline LLC
Firm Commitment: 200 Mmcf/d
COST: 1.85 $B
VOLUMES: 700 Mmcf/d
COST: 2.7 $B
VOLUMES: 1.1 Bcfe/d
ACRES: 149000 Acres
VOLUMES: 549 Mmcfe/d
ACRES: 325500 Acres
SPRING, Texas, April 25, 2019 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that it received the highest score among the 30 largest publicly-traded oil & gas producers in North America in a report by independent advocacy and investment advisory firms assessing water and chemical management practices.
SWN earned the top spot in "Disclosing the Facts 2019: Transparency and Risk in Water & Chemicals Management for Hydraulic Fracturing Operations" released by shareholder advocacy group As You Sow and investment advisory firm Boston Common Asset Management. SWN's place as the top-ranked company was based on a broad set of 25 criteria that examined how oil and gas companies use water and chemicals in their operations.
"Environmental stewardship, including water and chemical management, is a key tenet of our strategy. We are committed to transparency in our operations," said Bill Way, President and Chief Executive Officer, Southwestern Energy. Southwestern Energy has a well-established, comprehensive and thorough management approach to its operations that includes a number of steps to conserve water, reduce air emissions and protect the environment, he explained.
"The company has completed 10 projects that produced a combined fresh water benefit to the environment, where we work and live, totaling over 9 billion gallons in five years. Additionally, SWN received top marks for our practices in implementing and disclosing best methane reduction practices from the same two organizations. SWN has limited methane emissions from its Appalachian assets to 0.057 percent -- which is 96 percent lower than the national average."
As You Sow is a non-profit shareholder advocacy organization that promotes environmental and social corporate responsibility. Boston Common Asset Management is a sustainable investment advisory firm with a focus on corporate performance on environmental, social and governance issues.
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. For our Corporate Responsibility Report, visit www.swncr.com.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-scores-highest-in-north-american-oil--gas-industry-for-water-and-chemical-management-practices-300838544.html
SOURCE Southwestern Energy Company
HOUSTON and WHEELING, W.Va., March 7, 2019 /PRNewswire/ -- Southwestern Energy (NYSE: SWN) received top honors from the West Virginia Department of Environmental Protection for its reclamation work on well pad sites that were permitted in 2017-2018.
The company earned this distinction for the category recognizing an operator with more than 30 permits. This award is conferred in partnership with the Independent Oil and Gas Association of West Virginia and the West Virginia Oil and Natural Gas Association.
Candidates for the award are selected by an independent evaluation by state regulators during site inspections. The inspectors score the reclamation work on a scale of 0-99. Southwestern Energy had the highest scores in its category.
"We are pleased to receive this recognition for our efforts to reclaim our well sites," said Derek Cutright, senior vice president, Southwest Appalachia Division, Southwestern Energy. "Being a strong steward of the environment is a core value of how we operate and it's deeply ingrained in our culture."
The company has a broad range of efforts to lessen the impact of its operations on the environment, Cutright explains. These include initiatives to reduce the impact of its trucking activities by installing water lines to its production sites; investing in projects to treat acid mine drainage into rivers, and employing technology and best practices to be an industry leader in methane emissions reductions.
Southwestern Energy operates nearly 300,000 acres with multiple potential producing benches in West Virginia and manages over 400 producing wells. The company employs approximately 300 in the state with offices in Morgantown and Bethlehem, and has paid $99.7 million in total taxes and delivered more than $220 million in royalty and working interest payments to landowners.
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
View original content to download multimedia:http://www.prnewswire.com/news-releases/southwestern-energy-earns-top-honors-from-west-virginia-department-of-environmental-protection-300808740.html
SOURCE Southwestern Energy Company
SPRING, Texas, April 26, 2018 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced first quarter results ended March 31, 2018, along with other recent developments. Highlights include:
"We delivered a strong start to the year, meeting or exceeding all commitments for the quarter," said Bill Way, President and Chief Executive Officer of Southwestern Energy. "Momentum from growing liquids production and relentless delivery of operational and technical excellence, combined with our new credit facility, will improve margins in 2018 and into the future. These tangible steps demonstrate the growing value of our Appalachia assets and the strong confidence we have in repositioning the Company."
Financial Results |
For the three months ended | ||||
March 31, | |||||
2018 |
2017 | ||||
(in millions, except per share amounts) |
|||||
Operating income |
$ |
255 |
$ |
266 | |
Adjusted operating income (non-GAAP measure) |
$ |
264 |
$ |
266 | |
Net earnings attributable to common stock |
$ |
205 |
$ |
281 | |
Adjusted net income attributable to common stock (non-GAAP measure) |
$ |
162 |
$ |
87 | |
Earnings per diluted share |
$ |
0.36 |
$ |
0.57 | |
Adjusted earnings per diluted share (non-GAAP measure) |
$ |
0.28 |
$ |
0.18 | |
Net cash provided by operating activities |
$ |
364 |
$ |
312 | |
Net cash flow (non-GAAP measure) |
$ |
358 |
$ |
318 | |
Exploration and Production Financial Results |
For the three months ended | ||||
March 31, | |||||
2018 |
2017 | ||||
Production |
|||||
Northeast Appalachia (Bcf) |
108 |
87 | |||
Southwest Appalachia (Bcfe) |
51 |
36 | |||
Fayetteville (Bcf) |
67 |
81 | |||
Total production (Bcfe) |
226 |
204 | |||
% Natural Gas |
87% |
90% | |||
Average unit costs per Mcfe |
|||||
Lease operating expenses(1) |
$ |
0.94 |
$ |
0.89 | |
General & administrative expenses |
$ |
0.21 |
$ |
0.21 | |
Taxes, other than income taxes |
$ |
0.09 |
$ |
0.12 | |
Full cost pool amortization |
$ |
0.48 |
$ |
0.40 |
(1) |
The first quarter of 2018 included additional charges related to preventative maintenance associated with extended severe winter weather and a $3.7 million one-time charge related to NGL processing fees. |
Realized Prices |
For the three months ended | ||||
March 31, | |||||
2018 |
2017 | ||||
Natural Gas Price: |
|||||
NYMEX Henry Hub Price ($/MMBtu)(1) |
$ |
3.00 |
$ |
3.32 | |
Discount to NYMEX(2) |
$ |
(0.28) |
$ |
(0.59) | |
Average realized gas price per Mcf, excluding derivatives |
$ |
2.72 |
$ |
2.73 | |
Gain (loss) on settled financial basis derivatives ($/Mcf) |
$ |
(0.11) |
$ |
(0.01) | |
Gain (loss) on settled commodity derivatives ($/Mcf) |
$ |
0.06 |
$ |
(0.15) | |
Average realized gas price per Mcf, including derivatives |
$ |
2.67 |
$ |
2.57 | |
Oil Price: |
|||||
WTI Oil Price ($/Bbl) |
$ |
62.87 |
$ |
51.91 | |
Discount to WTI |
$ |
(6.86) |
$ |
(8.17) | |
Average realized oil price per Bbl |
$ |
56.01 |
$ |
43.74 | |
NGL Price: |
|||||
Average net realized NGL price per Bbl(3) |
$ |
15.43 |
$ |
13.28 | |
Percentage of WTI |
25% |
26% | |||
Average net realized C3+ NGL price per Bbl |
$ |
36.01 |
$ |
30.91 | |
Percentage of WTI |
57% |
60% | |||
Total Weighted Average Realized Price: |
|||||
Excluding derivatives |
$ |
2.81 |
$ |
2.75 | |
Including derivatives |
$ |
2.77 |
$ |
2.61 |
(1) |
Based on last day settlement prices from monthly futures contracts. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
(3) |
Includes the impact of transportation costs and $0.01 per Bbl and $0.02 per Bbl of realized derivative gains for the three months ended March 31, 2018 and March 31, 2017, respectively. |
First Quarter of 2018 Financial Results
Operating income was $255 million for the first quarter of 2018. E&P segment operating income of $238 million was 6% higher than the first quarter of 2017 driven by higher production and improved realized pricing, partially offset by higher operating costs associated with increased volumes. In the Appalachian Basin, net cash provided by operating activities increased to approximately $294 million for the first quarter of 2018, or 36%, compared to approximately $216 million during the first quarter of 2017.
During the first quarter of 2018, production increased by 11%, including a 37% increase in liquids production, compared to the first quarter of 2017. In the Appalachian Basin, production increased to 159 Bcfe or 1.77 Bcfe per day, an increase of 29% compared to the first quarter of 2017, despite the impact of winter weather.
The Company's realized natural gas price, excluding derivatives, was $2.72 per Mcf, comparable to the first quarter of 2017, despite a 10% decrease in NYMEX pricing. This includes a $0.31 per Mcf improvement in the discount to NYMEX prices, driven by Northeast Appalachia where the Company realized a $0.04 per Mcf premium to NYMEX for the first quarter of 2018. Additionally, NGL pricing, excluding derivatives, increased to $15.42 per Bbl, including C3+ pricing of $36.01 per Bbl, an increase of 16% compared to the first quarter of 2017. The increase in liquids production and realizations generated a $0.09 per Mcfe uplift to the Company's weighted average realized price excluding derivatives compared to a $0.02 per Mcfe uplift in the same period in 2017.
Midstream operating income, comprised of gathering and marketing activities, was $17 million for the first quarter of 2018, compared to $41 million for the same period of 2017. The change in operating income was driven by decreased gathered volumes associated with lower production and one-time compressor facility repair costs in the Fayetteville Shale and the impairment of an unrelated, non-core gathering asset.
Capital Structure and Investments – At March 31, 2017, the Company had cash of $958 million, gross debt of $4.4 billion and $3.4 billion in net debt. In April 2018, the Company entered into a new, five-year $3.5 billion secured revolving credit facility, supported by an initial borrowing base of $3.2 billion, with the Company electing an initial commitment of $2.0 billion. Pricing is based on LIBOR plus a margin of 150 to 250 basis points, depending on utilization. The new agreement is expected to reduce interest expense by approximately $20 million in 2018 and approximately $30 million annually in future years. This facility replaces the 2016 revolving credit and secured term loan bank facilities, with the prior term loan bank facility borrowings retired using cash on hand and borrowings under the new facility.
During the first quarter of 2018, Southwestern Energy invested total capital of $338 million. This included approximately $334 million invested in its E&P business and $4 million invested in the Midstream segment. Of the $338 million, approximately $28 million was associated with capitalized interest and $25 million was associated with capitalized expenses.
E&P Operational Review
During the first quarter of 2018, Southwestern Energy invested a total of approximately $334 million in its E&P business, and drilled 32 wells, completed 29 wells, and placed 33 wells to sales.
First Quarter 2018 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe)(1) |
108 |
51 |
67 | |||||
Gross operated production as of March 2018 (MMcfe/d)(2) |
1,421 |
963 |
1,053 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
99 |
$ |
146 |
$ |
10 | ||
Acquisition and leasehold |
2 |
18 |
− | |||||
Seismic and other |
1 |
2 |
1 | |||||
Capitalized interest and expense |
9 |
36 |
4 | |||||
Total capital investments |
$ |
111 |
$ |
202 |
$ |
15 | ||
Gross operated well count summary |
||||||||
Drilled |
9 |
21 |
2 | |||||
Completed |
13 |
15 |
1 | |||||
Wells to sales |
17 |
16 |
− | |||||
Average completed well cost (in millions)(3) |
$ |
6.2 |
$ |
8.8 |
$ |
− | ||
Average lateral length (in feet)(3) |
7,360 |
6,790 |
− | |||||
Realized natural gas price |
||||||||
NYMEX Henry Hub Price ($/MMBtu) |
$ |
3.00 |
$ |
3.00 |
$ |
3.00 | ||
Discount to NYMEX ($/Mcf)(4) |
$ |
0.04 |
$ |
(0.53) |
$ |
(0.72) | ||
Average realized gas price, excluding derivatives ($/Mcf) |
$ |
3.04 |
$ |
2.47 |
$ |
2.28 |
(1) |
Southwest Appalachia production included 22 Bcf of natural gas, 4,218 MBbls of NGLs and 594 MBbls of oil. |
(2) |
Temporarily restricted Fayetteville production rate due to compressor facility repairs. The rate on March 31, 2018 was 1,121 MMcf/d. |
(3) |
Southwest Appalachia includes only wells drilled and completed by SWN. |
(4) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
Southwest Appalachia – Southwestern Energy had total net production of 51 Bcfe, or 567 MMcfe per day, a 42% increase compared to the first quarter of 2017. Higher liquids production and realizations continue to drive margin expansion, with the increase in liquids realizations generating a price uplift of approximately $0.53 per Mcfe compared to its realized natural gas price of $2.75 per Mcf. Southwest Appalachia's weighted average realized price for the first quarter improved to $3.00 per Mcfe, which matched NYMEX gas price for the first quarter of 2018.
Southwestern Energy placed 16 wells to sales, 14 of which were drilled and completed by the Company. Twelve Company drilled and completed wells, targeting the Marcellus rich gas window, were online for at least 30 days and had an average lateral length of 6,950 feet with an average 30 day rate of approximately 8.4 MMcfe per day, comprised of 67% liquids. These 12 wells were producing over 130 MMcfe per day including over 5,000 Bbls per day of condensate at the end of the quarter, contributing to a 27% increase in Southwest Appalachia's quarter over quarter condensate exit rate. The Company continues to extend lateral lengths and drilled its longest well in Southwest Appalachia with a measured depth of over 20,000 feet and horizontal lateral over 13,400 feet.
Northeast Appalachia – The Company had total net production of 108 Bcf, or 1.2 Bcf per day, a 24% increase compared to the first quarter of 2017. Northeast Appalachia realized a premium of $0.04 per Mcf to NYMEX gas price, including transportation costs, and generated positive net cash flow from operating activities, net of capital, of approximately $115 million. The Company was able to take advantage of its firm transportation portfolio to capture increased pricing due to winter weather.
The Company placed 17 wells to sales in the first quarter, all in Susquehanna County. The average rate for the first 30 days for the 8 wells that were online for at least 30 days was 15.2 MMcf per day per well. In March, the Watts 1H well was placed to sales and was drilled with a lateral length of over 11,200 feet and had an initial production rate of 34.1 MMcf per day, further demonstrating improved capital efficiency that will continue to be targeted throughout the area.
The Company is driving further improvements in its Tioga area economics by lowering projected completion costs through water infrastructure installation and increasing lateral lengths. The Company commissioned dedicated third-party water infrastructure in Tioga, expected to reduce completion costs by approximately $400,000 per well by the middle of 2018. Additionally, the latest 3-well pad drilled in Tioga had an average lateral length of over 10,800 feet, a 45% improvement compared to historical drilled wells in this area.
Fayetteville Shale – The Company drilled two additional wells that were placed to sales in mid-April as part of its field-wide redevelopment program, which utilizes advanced completion designs and optimized landing zones to improve well performance. The Sisson well had a lateral length of 8,642 feet and an initial production rate of approximately 8 MMcf per day. The Guinn James well had a lateral length of 4,944 feet and an initial production rate of approximately 6 MMcf per day. This well is currently in the early stages of flowback and is still cleaning up. Additionally, the Company's cumulative production from its initial redevelopment well, the McNew, is further outperforming historical production in the area by over 60% in the first 180 days online. These well results, supported by the Company's big data analytics, further confirm Fayetteville's low-risk redevelopment opportunities.
Hedging Update
Southwestern Energy continues to execute a disciplined hedging program with physical, financial and basis hedges on its forecasted natural gas and natural gas liquids production. As of April 24, 2018, the Company had approximately 434 Bcf of its remaining 2018 forecasted gas production volumes protected at an average swap or purchased put strike price of $2.97 per Mcf. Approximately half of these protected volumes retain upside exposure up to $3.37 Mcf. Additionally, the Company had approximately 311 Bcf of its 2019 forecasted gas production protected at an average swap or purchased put strike price of $2.92 per Mcf, with upside exposure on approximately 60%, or 186 Bcf, of those protected volumes up to $3.24 per Mcf.
A detailed breakdown of the Company's natural gas derivative financial instruments as of April 24, 2018 is shown below. Please refer to our quarterly report on Form 10-Q to be filed with the Securities and Exchange Commission for complete information on the Company's commodity, basis and interest rate protection.
Weighted Average Price per MMBtu | |||||||||||||
Volume |
Swaps |
Sold Puts |
Purchased |
Sold Calls | |||||||||
Financial protection on production |
|||||||||||||
2018 |
|||||||||||||
Fixed price swaps |
215 |
$ |
2.97 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
6 |
– |
– |
2.90 |
3.27 | ||||||||
Three-way costless collars |
213 |
– |
2.40 |
2.97 |
3.37 | ||||||||
Total |
434 |
||||||||||||
2019 |
|||||||||||||
Fixed price swaps |
126 |
$ |
2.95 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
53 |
– |
– |
2.80 |
2.98 | ||||||||
Three-way costless collars |
133 |
– |
2.49 |
2.93 |
3.34 | ||||||||
Total |
311 |
||||||||||||
2020 |
|||||||||||||
Fixed price swaps |
2 |
$ |
2.77 |
$ |
– |
$ |
– |
$ |
– | ||||
Three-way costless collars |
38 |
– |
2.44 |
2.80 |
3.00 | ||||||||
Total |
40 |
Note: Amounts may not sum due to rounding |
Other Derivative Contracts
|
Volume |
Weighted Average | |||
Purchased call options |
|||||
2020 |
68 |
$ |
3.63 | ||
2021 |
57 |
3.52 | |||
Total |
125 |
||||
Sold call options |
|||||
2018 |
47 |
$ |
3.50 | ||
2019 |
52 |
3.50 | |||
2020 |
137 |
3.39 | |||
2021 |
114 |
3.33 | |||
Total |
350 |
As of April 24, 2018, the Company had also taken steps to mitigate the volatility of basis differentials by protecting basis on approximately 320 Bcf of its remaining 2018 forecasted natural gas production at a basis differential to NYMEX natural gas prices of approximately ($0.43) per Mcf, which includes the impact of both physical and financial basis hedges. A detailed breakdown of the Company's financial basis positions as of April 24, 2018 is shown below:
Financial basis positions (excludes physical positions) |
Volume |
Basis Differential | |||
Q2 2018 |
|||||
Dominion South |
17.5 |
$ |
(0.68) | ||
TETCO M3 |
11.4 |
(0.51) | |||
Total |
28.9 |
$ |
(0.62) | ||
2018 |
|||||
Dominion South |
44.1 |
$ |
(0.66) | ||
TETCO M3 |
29.2 |
(0.49) | |||
Total |
73.3 |
$ |
(0.59) | ||
2019 |
|||||
Dominion South |
1.0 |
$ |
(0.63) | ||
TETCO M3 |
6.8 |
1.38 | |||
Total |
7.8 |
$ |
1.11 |
Note: 2018 includes Q2 2018 positions |
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three months ended March 31, 2018 and March 31, 2017 and December 31, 2017, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended March 31, | |||||
2018 |
2017 | ||||
(in millions) | |||||
Net income attributable to common stock: |
|||||
Net income attributable to common stock |
$ |
205 |
$ |
281 | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
1 |
30 | |||
Impairment of non-core gathering assets |
10 |
− | |||
Gain on certain derivatives |
(2) |
(146) | |||
Gain on sale of assets |
(1) |
(1) | |||
Loss on early extinguishment of debt |
− |
1 | |||
Adjustments due to inventory valuation |
3 |
− | |||
Adjustments due to discrete tax items(1) |
(51) |
(134) | |||
Tax impact on adjustments |
(3) |
56 | |||
Adjusted net income attributable to common stock |
$ |
162 |
$ |
87 |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance. |
3 Months Ended March 31, | |||||
2018 |
2017 | ||||
Diluted earnings per share: |
|||||
Diluted earnings per share |
$ |
0.36 |
$ |
0.57 | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
0.00 |
0.06 | |||
Impairment of non-core gathering assets |
0.02 |
− | |||
Gain on certain derivatives |
(0.00) |
(0.30) | |||
Gain on sale of assets |
(0.00) |
(0.00) | |||
Loss on early extinguishment of debt |
− |
0.00 | |||
Adjustments due to inventory valuation |
0.00 |
− | |||
Adjustments due to discrete tax items(1) |
(0.09) |
(0.27) | |||
Tax impact on adjustments |
(0.01) |
0.12 | |||
Adjusted diluted earnings per share |
$ |
0.28 |
$ |
0.18 |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance. |
3 Months Ended March 31, | |||||
2018 |
2017 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
364 |
$ |
312 | |
Add back: |
|||||
Changes in operating assets and liabilities |
(6) |
6 | |||
Net cash flow |
$ |
358 |
$ |
318 | |
3 Months Ended March 31, | |||||
2018 |
2017 | ||||
(in millions) | |||||
Operating income: |
|||||
Operating income |
$ |
255 |
$ |
266 | |
Add back: |
|||||
Gain on sale of assets |
(1) |
– | |||
Impairment of non-core gathering assets |
10 |
– | |||
Adjusted operating income |
$ |
264 |
$ |
266 | |
3 Months Ended March 31, | |||||
2018 |
2017 | ||||
(in millions) | |||||
Midstream segment operating income: |
|||||
Operating income |
$ |
17 |
$ |
41 | |
Add back: |
|||||
Gain on sale of assets |
(1) |
– | |||
Impairment of non-core gathering assets |
10 |
– | |||
Adjusted operating income |
$ |
26 |
$ |
41 | |
March 31, |
December 31, | ||||
2018 |
2017 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
4,393 |
$ |
4,391 | |
Subtract: |
|||||
Cash and cash equivalents |
(958) |
(916) | |||
Net debt |
$ |
3,435 |
$ |
3,475 | |
Southwestern management will host a conference call on Friday, April 27, 2018 at 9:00 am Central to discuss its first quarter 2018 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The conference will also be webcast at www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
Cautionary Note to U.S. Investors – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves. We use the term "EUR" in this release that the SEC's guidelines prohibit us from including in filings with the SEC. U.S. investors are urged to consider closely the oil and gas disclosures in our Form 10-K and other reports and filings with the SEC. Copies are available from the SEC and from the Southwestern Energy Company website.
OPERATING STATISTICS (Unaudited) | |||||
Southwestern Energy Company and Subsidiaries | |||||
For the three months ended | |||||
March 31, | |||||
2018 |
2017 | ||||
Exploration & Production |
|||||
Production |
|||||
Gas production (Bcf) |
197 |
183 | |||
Oil production (MBbls) |
613 |
519 | |||
NGL production (MBbls) |
4,230 |
3,008 | |||
Total production (Bcfe) |
226 |
204 | |||
Commodity Prices |
|||||
Average realized gas price per Mcf, including derivatives |
$ |
2.67 |
$ |
2.57 | |
Average realized gas price per Mcf, excluding derivatives |
$ |
2.72 |
$ |
2.73 | |
Average realized oil price per Bbl |
$ |
56.01 |
$ |
43.74 | |
Average realized NGL price per Bbl, including derivatives |
$ |
15.43 |
$ |
13.28 | |
Summary of Derivative Activity in the Statement of Operations |
|||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(9) |
$ |
(30) | |
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
– |
$ |
145 | |
Average unit costs per Mcfe |
|||||
Lease operating expenses |
$ |
0.94 |
$ |
0.89 | |
General & administrative expenses |
$ |
0.21 |
$ |
0.21 | |
Taxes, other than income taxes |
$ |
0.09 |
$ |
0.12 | |
Full cost pool amortization |
$ |
0.48 |
$ |
0.40 | |
Midstream |
|||||
Volumes marketed (Bcfe) |
265 |
245 | |||
Volumes gathered (Bcf) |
103 |
129 |
STATEMENTS OF OPERATIONS (Unaudited) | ||||||
Southwestern Energy Company and Subsidiaries | ||||||
For the three months ended | ||||||
March 31, | ||||||
2018 |
2017 | |||||
(in millions, except share/per share amounts) |
||||||
Operating Revenues |
||||||
Gas sales |
$ |
540 |
$ |
503 | ||
Oil sales |
35 |
23 | ||||
NGL sales |
65 |
40 | ||||
Marketing |
253 |
253 | ||||
Gas gathering |
24 |
27 | ||||
Other |
3 |
– | ||||
920 |
846 | |||||
Operating Costs and Expenses |
||||||
Marketing purchases |
255 |
251 | ||||
Operating expenses |
189 |
147 | ||||
General and administrative expenses |
55 |
50 | ||||
Depreciation, depletion and amortization |
143 |
106 | ||||
Taxes, other than income taxes |
23 |
26 | ||||
665 |
580 | |||||
Operating Income |
255 |
266 | ||||
Interest Expense |
||||||
Interest on debt |
65 |
58 | ||||
Other interest charges |
2 |
2 | ||||
Interest capitalized |
(28) |
(28) | ||||
39 |
32 | |||||
Gain (Loss) on Derivatives |
(7) |
116 | ||||
Other Income (Loss), Net |
(1) |
1 | ||||
Income Before Income Taxes |
208 |
351 | ||||
Benefit for Income Taxes |
||||||
Current |
– |
– | ||||
Deferred |
– |
– | ||||
– |
– | |||||
Net Income |
$ |
208 |
$ |
351 | ||
Mandatory convertible preferred stock dividend |
– |
27 | ||||
Participating securities - mandatory convertible preferred stock |
3 |
43 | ||||
Net Income Attributable to Common Stock |
$ |
205 |
$ |
281 | ||
Income Per Common Share |
||||||
Basic |
$ |
0.36 |
$ |
0.57 | ||
Diluted |
$ |
0.36 |
$ |
0.57 | ||
Weighted Average Common Shares Outstanding |
||||||
Basic |
571,297,804 |
493,068,000 | ||||
Diluted |
573,844,459 |
494,494,995 |
BALANCE SHEETS (Unaudited) | ||||||
Southwestern Energy Company and Subsidiaries | ||||||
March 31, |
December 31, | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,488 |
$ |
1,509 | ||
Property and equipment |
26,104 |
25,769 | ||||
Less: Accumulated depreciation, depletion and amortization |
(20,136) |
(19,997) | ||||
Total property and equipment, net |
5,968 |
5,772 | ||||
Other long-term assets |
257 |
240 | ||||
Total assets |
$ |
7,713 |
$ |
7,521 | ||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
$ |
732 |
$ |
780 | ||
Long-term debt |
4,393 |
4,391 | ||||
Pension and other postretirement liabilities |
58 |
58 | ||||
Other long-term liabilities |
337 |
313 | ||||
Total liabilities |
5,520 |
5,542 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 586,833,276 shares as of March 31, 2018 and 512,134,311 as of December 31, 2017 |
6 |
5 | ||||
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of December 31, 2017, converted to common stock on January 12, 2018 |
– |
– | ||||
Additional paid-in capital |
4,703 |
4,698 | ||||
Accumulated deficit |
(2,471) |
(2,679) | ||||
Accumulated other comprehensive loss |
(44) |
(44) | ||||
Common stock in treasury; 31,269 shares as of March 31, 2018 and December 31, 2017 |
(1) |
(1) | ||||
Total equity |
2,193 |
1,979 | ||||
Total liabilities and equity |
$ |
7,713 |
$ |
7,521 |
STATEMENTS OF CASH FLOWS (Unaudited) | ||||||
Southwestern Energy Company and Subsidiaries | ||||||
For the three months ended | ||||||
March 31, | ||||||
2018 |
2017 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities: |
||||||
Net income |
$ |
208 |
$ |
351 | ||
Adjustments to reconcile net income to net cash provided by operating activities: |
||||||
Depreciation, depletion and amortization |
143 |
106 | ||||
Amortization of debt issuance costs |
2 |
2 | ||||
Gain on derivatives, unsettled |
(2) |
(146) | ||||
Stock-based compensation |
4 |
6 | ||||
Other |
3 |
(1) | ||||
Change in assets and liabilities |
6 |
(6) | ||||
Net cash provided by operating activities |
364 |
312 | ||||
Cash Flows From Investing Activities: |
||||||
Capital investments |
(302) |
(340) | ||||
Proceeds from sale of property and equipment |
6 |
2 | ||||
Other |
2 |
4 | ||||
Net cash used in investing activities |
(294) |
(334) | ||||
Cash Flows From Financing Activities: |
||||||
Payments on current portion of long-term debt |
– |
(25) | ||||
Change in bank drafts outstanding |
– |
6 | ||||
Preferred stock dividend |
(27) |
– | ||||
Cash paid for tax withholding |
(1) |
– | ||||
Net cash used in financing activities |
(28) |
(19) | ||||
Increase (decrease) in cash and cash equivalents |
42 |
(41) | ||||
Cash and cash equivalents at beginning of year |
916 |
1,423 | ||||
Cash and cash equivalents at end of period |
$ |
958 |
$ |
1,382 |
SEGMENT INFORMATION (Unaudited) | |||||||||||||||
Southwestern Energy Company and Subsidiaries | |||||||||||||||
Exploration |
|||||||||||||||
and |
Midstream |
||||||||||||||
(in millions) |
Production |
Services |
Other |
Eliminations |
Total | ||||||||||
Three months ended March 31, 2018 |
|||||||||||||||
Revenues |
$ |
637 |
$ |
896 |
$ |
– |
$ |
(613) |
$ |
920 | |||||
Marketing purchases |
– |
819 |
– |
(564) |
255 | ||||||||||
Operating expenses |
213 |
25 |
– |
(49) |
189 | ||||||||||
General and administrative expenses |
48 |
7 |
– |
– |
55 | ||||||||||
Depreciation, depletion and amortization |
117 |
26 |
– |
– |
143 | ||||||||||
Taxes, other than income taxes |
21 |
2 |
– |
– |
23 | ||||||||||
Operating income |
238 |
17 |
(2) |
– |
– |
255 | |||||||||
Capital investments(1) |
334 |
4 |
– |
– |
338 | ||||||||||
Three months ended March 31, 2017 |
|||||||||||||||
Revenues |
$ |
563 |
$ |
858 |
$ |
– |
$ |
(575) |
$ |
846 | |||||
Marketing purchases |
– |
765 |
– |
(514) |
251 | ||||||||||
Operating expenses |
181 |
27 |
– |
(61) |
147 | ||||||||||
General and administrative expenses |
43 |
7 |
– |
– |
50 | ||||||||||
Depreciation, depletion and amortization |
90 |
16 |
– |
– |
106 | ||||||||||
Taxes, other than income taxes |
24 |
2 |
– |
– |
26 | ||||||||||
Operating income |
225 |
41 |
– |
– |
266 | ||||||||||
Capital investments(1) |
283 |
6 |
1 |
– |
290 |
(1) |
Capital investments includes an increase of $33 million and a decrease of $52 million for the three months ended March 31, 2018 and 2017, respectively, relating to the change in accrued expenditures between periods. |
(2) |
Includes a $10 million impairment related to certain non-core gathering assets and a $1 million gain from the sale of certain compressor equipment. |
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-first-quarter-2018-results-300637796.html
SOURCE Southwestern Energy Company
HOUSTON, April 16, 2018 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2018 First Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, April 27, 2018, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's First Quarter 2018 Earnings |
When: |
April 27, 2017 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live Webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
View original content:http://www.prnewswire.com/news-releases/webcast-alert-southwestern-energy-company-invites-you-to-join-its-first-quarter-2018-earnings-conference-call-on-the-web-300628393.html
SOURCE Southwestern Energy Company
HOUSTON, March 1, 2018 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the fourth quarter and the year ended December 31, 2017. The Company met or exceeded its guidance and delivered on each of its commitments in the fourth quarter. Fiscal year 2017 highlights include:
"Southwestern Energy delivered solid financial and operational results in 2017. There is clear evidence of upside in our assets, as the value of our PV10 reserves alone is well above current enterprise value," said Bill Way, President and Chief Executive Officer. "Our focus in 2018 will be on exploring strategic alternatives for Fayetteville Shale assets, accelerating development in Appalachia and reducing structural costs as we reposition the Company to compete and win in any commodity price environment for years to come. Building on the momentum from our leading technical and operational expertise and our demonstrated financial discipline, underpinned by our Formula that guides everything we do, we are well positioned to drive increasing value for our shareholders."
The Company invested within cash flow (supplemented by the previously announced remaining $200 million from its 2016 equity offering as planned) while investing in its highest return projects. Below is a summary of fourth quarter and full year 2017 results.
Financial Results |
For the three months ended |
For the year ended | |||||||||
December 31, |
December 31, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
(in millions, except per share amounts) |
|||||||||||
Operating income (loss) |
$ |
167 |
$ |
122 |
$ |
731 |
$ |
(2,195) | |||
Adjusted operating income (non-GAAP measure) |
$ |
169 |
$ |
134 |
$ |
735 |
$ |
215 | |||
Net income (loss) attributable to common stock |
$ |
267 |
$ |
(237) |
$ |
815 |
$ |
(2,751) | |||
Adjusted net income (loss) attributable to common stock (non-GAAP measure) |
$ |
63 |
$ |
39 |
$ |
219 |
$ |
(7) | |||
Diluted earnings (loss) per share |
$ |
0.53 |
$ |
(0.48) |
$ |
1.63 |
$ |
(6.32) | |||
Adjusted diluted earnings (loss) per share (non-GAAP measure) |
$ |
0.12 |
$ |
0.08 |
$ |
0.44 |
$ |
(0.01) | |||
Net cash provided by operating activities |
$ |
308 |
$ |
161 |
$ |
1,097 |
$ |
498 | |||
Net cash flow (non-GAAP measure) |
$ |
322 |
$ |
211 |
$ |
1,138 |
$ |
645 |
Exploration and Production Financial Results |
For the three months ended |
For the year ended | |||||||||
December 31, |
December 31, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Production |
|||||||||||
Fayetteville (Bcf) |
75 |
86 |
316 |
375 | |||||||
Northeast Appalachia (Bcf) |
110 |
82 |
395 |
350 | |||||||
Southwest Appalachia (Bcfe) |
52 |
33 |
183 |
148 | |||||||
Other (Bcfe) |
2 |
1 |
3 |
2 | |||||||
Total production (Bcfe) |
239 |
202 |
897 |
875 | |||||||
% Natural Gas |
88% |
90% |
89% |
90% | |||||||
Average unit costs per Mcfe |
|||||||||||
Lease operating expenses |
$ |
0.91 |
$ |
0.87 |
$ |
0.90 |
$ |
0.87 | |||
General & administrative expenses(1) |
$ |
0.22 |
$ |
0.27 |
$ |
0.22 |
$ |
0.22 | |||
Taxes, other than income taxes(2) |
$ |
0.07 |
$ |
0.11 |
$ |
0.10 |
$ |
0.10 | |||
Full cost pool amortization |
$ |
0.48 |
$ |
0.30 |
$ |
0.45 |
$ |
0.38 |
(1) |
Excludes legal settlements for the year ended December 31, 2017 and restructuring and other one-time charges for the three months and year ended December 31, 2016, respectively. |
(2) |
Excludes restructuring charges for the year ended December 31, 2016. |
Realized Prices |
For the three months ended |
For the year ended | |||||||||
December 31, |
December 31, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Natural Gas Price: |
|||||||||||
NYMEX Henry Hub Price ($/MMBtu)(1) |
$ |
2.93 |
$ |
2.98 |
$ |
3.11 |
$ |
2.46 | |||
Discount to NYMEX(2) |
(0.93) |
(0.98) |
(0.88) |
(0.87) | |||||||
Average realized gas price per Mcf, excluding hedges |
$ |
2.00 |
$ |
2.00 |
$ |
2.23 |
$ |
1.59 | |||
Gain (loss) on settled financial basis derivatives ($/Mcf) |
0.07 |
0.09 |
(0.01) |
0.03 | |||||||
Gain (loss) on settled commodity derivatives ($/Mcf) |
0.05 |
(0.02) |
(0.03) |
0.02 | |||||||
Average realized gas price per Mcf, including hedges |
$ |
2.12 |
$ |
2.07 |
$ |
2.19 |
$ |
1.64 | |||
Oil Price: |
|||||||||||
WTI oil price ($/Bbl) |
$ |
55.40 |
$ |
49.29 |
$ |
50.96 |
$ |
43.32 | |||
Discount to WTI |
(7.35) |
(8.11) |
(7.84) |
(12.12) | |||||||
Average oil price per Bbl |
$ |
48.05 |
$ |
41.18 |
$ |
43.12 |
$ |
31.20 | |||
NGL Price: |
|||||||||||
Average net realized NGL price per Bbl(3) |
$ |
17.98 |
$ |
12.08 |
$ |
14.48 |
$ |
7.46 | |||
Percentage of WTI |
32% |
25% |
28% |
17% | |||||||
Average net realized C3+ NGL price per Bbl |
$ |
39.38 |
$ |
27.91 |
$ |
30.08 |
$ |
17.75 | |||
Percentage of WTI |
71% |
57% |
59% |
41% |
(1) |
Based on last day settlement prices from monthly futures contracts. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
(3) |
Includes the impact of transportation costs and $0.01 per Bbl and $0.02 per Bbl of realized hedge gains for the three and twelve months ended December 31, 2017. |
Fourth Quarter 2017 Financial Results
E&P Segment –Operating income for the segment improved to $114 million for the fourth quarter of 2017, compared to operating income of $82 million during the fourth quarter of 2016. The increase in operating income was primarily due to higher production and liquids pricing, partially offset by higher operating costs.
Midstream Segment – Operating income for the segment, comprised of gathering and marketing activities, was $54 million for the fourth quarter of 2017, compared to $40 million for the same period in 2016. The increase in operating income was primarily a result of $14 million minimum volume commitment shortfall payment from a third-party customer to the Company's gathering segment and increase in the Company's marketing margin. The increase was offset by a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale.
Full Year 2017 Financial Results
E&P Segment – Operating income for the segment improved to $549 million for 2017, compared to an operating loss of approximately $2.4 billion for 2016, which was primarily due to the $2.3 billion impairment of natural gas and oil properties and $75 million in restructuring charges during this period last year. The increase in operating income in 2017 was primarily due to the absence of impairments and restructuring charges and higher realized natural gas and liquids pricing.
Midstream Segment – Operating income for the segment, comprised of gathering and marketing activities, was $183 million for 2017, which included a $6 million gain on sale of equipment, compared to $209 million for the same period in 2016, which included $3 million in restructuring charges. The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale.
Capital Structure and Investments – At December 31, 2017, the Company had total debt of approximately $4.4 billion and cash and cash equivalents of $916 million, resulting in net debt of $3.5 billion. Net debt to adjusted EBITDA ratio improved 38% to 2.8 times, compared to 4.5 times at December 31, 2016. During 2017, the Company took steps to improve its maturity schedule and now has only $92 million in bonds due prior to 2022. The undrawn revolver and the cash maintained on the balance sheet anchor the strong liquidity position the Company has built and intends to maintain as part of its disciplined financial plan.
During 2017, Southwestern invested a total of $1.3 billion in capital. This included approximately $1.25 billion invested in its E&P business, $32 million invested in its Midstream segment and $13 million invested for corporate and other purposes. Of the $1.3 billion, approximately $113 million was associated with capitalized interest and $104 million was associated with capitalized expenses.
2017 Operational Review
During the fourth quarter of 2017, Southwestern invested a total of approximately $327 million in the E&P business and drilled 28 wells, completed 35 wells, and placed 36 wells to sales.
Three Months Ended Dec 31, 2017 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) (1) |
110 |
52 |
75 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
105 |
$ |
109 |
$ |
9 | ||
Acquisition and leasehold |
2 |
13 |
- | |||||
Seismic and other |
4 |
1 |
3 | |||||
Capitalized interest and expense |
11 |
34 |
5 | |||||
Total capital investments |
$ |
122 |
$ |
157 |
$ |
17 | ||
Gross operated well count summary |
||||||||
Drilled |
11 |
17 |
- | |||||
Completed |
22 |
12 |
1 | |||||
Wells to sales |
23 |
11 |
2 | |||||
Realized Price |
||||||||
NYMEX Henry Hub Price ($/MMBtu) |
$ |
2.93 |
$ |
2.93 |
$ |
2.93 | ||
Discount to NYMEX ($/Mcf)(2) |
$ |
(1.08) |
$ |
(0.93) |
$ |
(0.71) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
1.85 |
$ |
2.00 |
$ |
2.22 |
(1) |
Southwest Appalachia production included 25 Bcf of natural gas, 4,095 MBbls of NGLs and 555 MBbls of oil. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
During 2017, Southwestern invested a total of approximately $1.25 billion in the E&P business, and drilled 134 wells, completed 151 wells, placed 166 wells to sales and had 92 wells in progress at year-end. Of these 92 wells, 52 and 40 were located in our Northeast Appalachia and Southwest Appalachia, respectively, and 19 of these wells are waiting on pipeline or production facilities.
Year-end 2017 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) (1) |
395 |
183 |
316 | |||||
Gross operated production at year-end 2017 (Mmcfe/d)(2) |
1,446 |
901 |
1,170 | |||||
Reserves (Bcfe) |
4,126 |
6,962 |
3,679 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
420 |
$ |
353 |
$ |
82 | ||
Acquisition and leasehold |
14 |
59 |
1 | |||||
Seismic and other |
13 |
4 |
9 | |||||
Capitalized interest and expense |
42 |
131 |
22 | |||||
Total capital investments |
$ |
489 |
$ |
547 |
$ |
114 | ||
Gross operated well count summary |
||||||||
Drilled |
67 |
53 |
13 | |||||
Completed |
77 |
50 |
23 | |||||
Wells to sales |
83 |
57 |
25 | |||||
Wells in progress |
52 |
40 |
- | |||||
Year-end drilled uncompleted wells |
30 |
36 |
- | |||||
Realized price |
||||||||
NYMEX Henry Hub price ($/MMBtu) |
$ |
3.11 |
$ |
3.11 |
$ |
3.11 | ||
Discount to NYMEX ($/Mcf) (3) |
$ |
(1.00) |
$ |
(0.83) |
$ |
(0.76) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
2.11 |
$ |
2.28 |
$ |
2.35 |
(1) |
SW Appalachia production included 85 Bcf of natural gas, 14,193 MBbls of NGLs and 2,228 MBbls of oil. |
(2) |
Based on average rates for the month of December 2017. |
(3) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
For the years ended December 31, | |||||
2017 |
2016 | ||||
E&P Capital Investments by Type |
(in millions) | ||||
Exploratory and development drilling, including workovers |
$ |
878 |
$ |
358 | |
Acquisitions and leasehold |
86 |
23 | |||
Seismic expenditures |
7 |
1 | |||
Drilling rigs, sand facility, water infrastructure and other |
65 |
2 | |||
Capitalized interest and other expenses |
212 |
239 | |||
Total E&P capital investments |
$ |
1,248 |
$ |
623 | |
E&P Capital Investments by Area |
|||||
Northeast Appalachia |
$ |
447 |
$ |
165 | |
Southwest Appalachia |
416 |
130 | |||
Fayetteville Shale |
92 |
65 | |||
Exploration |
24 |
(2) | |||
E&P Services & Other |
57 |
26 | |||
Capitalized interest and other expenses |
212 |
239 | |||
Total E&P capital investments |
$ |
1,248 |
$ |
623 |
Southwest Appalachia – Southwest Appalachia's gross operated exit production rate increased by 56%, compared to December 2016, to approximately 901 MMcfe per day. Southwestern brought online 57 wells in Southwest Appalachia in 2017, which included 46 Marcellus wells drilled and completed by Southwestern. The 46 wells included 27 targeting the rich gas window, 16 targeting the lean gas window and 3 targeting dry gas Marcellus. The 46 wells had an average lateral length of 7,451 feet and an average cost of $7.4 million per well. This compares to an average completed operated well cost of $5.4 million per well and an average horizontal lateral length of 5,275 feet in 2016. In 2017, the Company continued its completion optimization efforts to improve well performance. Southwest Appalachia increased stage density and sand loading by 20% and 14%, respectively in 2017 and increased its average horizontal lateral length by over 2,000 feet, or 41%, compared to 2016. These efforts on drilling longer laterals, driving down costs and increasing operational efficiency were able to more than offset the additional cost of higher intensity completions, yielding higher well productivity and higher well level returns. The Company will focus on further extending lateral lengths on future wells to create additional value that has been demonstrated on the long lateral wells drilled to date.
Operational Highlights:
Northeast Appalachia – Northeast Appalachia's gross operated exit production rate increased 32% compared to December 2016, to approximately 1,446 MMcfe per day. In 2017, the Company's operated horizontal wells had an average completed well cost of $5.9 million per well and an average horizontal lateral length of 6,185 feet. This compares to an average completed operated well cost of $5.3 million per well and an average horizontal lateral length of 6,142 feet in 2016. The increased costs were primarily due to increased activity in delineation areas. The increase in costs were more than offset by efficiency and productivity gains, resulting in a 7% improvement in finding & development costs.
Operational Highlights:
Fayetteville Shale – The Company generated approximately $400 million in positive cash flow from operations, net of capital investments from its Fayetteville E&P and midstream gathering assets in 2017.
Operational Highlights:
2017 Natural Gas and Oil Reserves
Southwestern's estimated proved natural gas and oil reserves, audited by an independent petroleum engineering firm, increased by 181% to approximately 14,775 Bcfe at December 31, 2017. The following tables detail additional information relating to reserve estimates as of and for the year ended December 31, 2017:
Proved Reserves Summary |
For the years ended December 31, | ||||||
2017 |
2016 | ||||||
Proved reserves (in Bcfe) |
14,775 |
5,253 | |||||
Prices used |
|||||||
Natural gas (per Mcf) |
$ |
2.98 |
$ |
2.48 | |||
Oil (per barrel) |
$ |
47.79 |
$ |
39.25 | |||
NGL (per barrel) |
$ |
14.41 |
$ |
6.74 | |||
PV-10: |
|||||||
Pre-Tax (millions) |
$ |
5,784 |
$ |
1,665 | |||
PV of Taxes (millions) |
(222) |
– | |||||
After-Tax (millions) |
$ |
5,562 |
$ |
1,665 | |||
Percent of estimated proved reserves that are: |
|||||||
Natural gas |
75% |
93% | |||||
Proved developed |
54% |
99% |
2017 Proved Reserves by Commodity |
Natural Gas |
Oil |
NGL |
Total | |||
(Bcf) |
(MBbls) |
(MBbls) |
(Bcfe) | ||||
Proved reserves, beginning of year |
4,866 |
10,523 |
53,931 |
5,253 | |||
Revisions of previous estimates |
1,898 |
1,668 |
70,549 |
2,332 | |||
Extensions, discoveries and other additions(1) |
5,159 |
55,772 |
432,220 |
8,087 | |||
Production |
(797) |
(2,327) |
(14,245) |
(897) | |||
Acquisition of reserves in place |
– |
– |
– |
– | |||
Disposition of reserves in place |
– |
– |
– |
– | |||
Proved reserves, end of year |
11,126 |
65,636 |
542,455 |
14,775 | |||
Proved developed reserves: |
|||||||
Beginning of year |
4,789 |
10,523 |
53,931 |
5,176 | |||
End of year |
6,979 |
14,513 |
142,213 |
7,920 |
Note: Amounts may not add due to rounding | |
(1) |
The 2017 PUD additions are primarily associated with the increase in commodity prices. |
2017 Proved Reserves by Division |
Appalachia |
Fayetteville |
||||||||
Northeast |
Southwest |
Shale |
Other |
Total | ||||||
Estimated Proved Reserves (Bcfe): |
||||||||||
Reserves, beginning of year |
1,574 |
677 |
2,997 |
5 |
5,253 | |||||
Production |
(395) |
(183) |
(316) |
(3) |
(897) | |||||
Extensions, discoveries and other additions(1) |
1,890 |
5,605 |
591 |
1 |
8,087 | |||||
Price revisions |
903 |
738 |
49 |
1 |
1,691 | |||||
Performance & production revisions |
154 |
125 |
358 |
4 |
641 | |||||
Reserves, end of year |
4,126 |
6,962 |
3,679 |
8 |
14,775 |
(1) |
The 2017 PUD additions are primarily associated with the increase in commodity prices. |
2017 PROVED RESERVES BY CATEGORY AND SUMMARY OPERATING DATA | ||||||||||||||
Appalachia |
Fayetteville |
|||||||||||||
Northeast |
Southwest |
Shale |
Other (1) |
Total | ||||||||||
Estimated Proved Reserves: |
||||||||||||||
Natural Gas (Bcf): |
||||||||||||||
Developed (Bcf) |
3,007 |
833 |
3,135 |
4 |
6,979 | |||||||||
Undeveloped (Bcf) |
1,119 |
2,484 |
544 |
– |
4,147 | |||||||||
4,126 |
3,317 |
3,679 |
4 |
11,126 | ||||||||||
Crude Oil (MMBbls): |
||||||||||||||
Developed (MMBbls) |
– |
14.2 |
– |
0.3 |
14.5 | |||||||||
Undeveloped (MMBbls) |
– |
51.1 |
– |
– |
51.1 | |||||||||
– |
65.3 |
– |
0.3 |
65.6 | ||||||||||
Natural Gas Liquids (MMBbls): |
||||||||||||||
Developed (MMBbls) |
– |
141.9 |
– |
0.3 |
142.2 | |||||||||
Undeveloped (MMBbls) |
– |
400.2 |
– |
– |
400.2 | |||||||||
– |
542.1 |
– |
0.3 |
542.4 | ||||||||||
Total Proved Reserves (Bcfe) (2): |
||||||||||||||
Developed (Bcfe) |
3,007 |
1,770 |
3,135 |
8 |
7,920 | |||||||||
Undeveloped (Bcfe) |
1,119 |
5,192 |
544 |
– |
6,855 | |||||||||
4,126 |
6,962 |
3,679 |
8 |
14,775 | ||||||||||
Percent of Total |
28% |
47% |
25% |
0% |
100% | |||||||||
Percent Proved Developed |
73% |
25% |
85% |
100% |
54% | |||||||||
Percent Proved Undeveloped |
27% |
75% |
15% |
0% |
46% | |||||||||
Production (Bcfe) |
395 |
183 |
316 |
3 |
897 | |||||||||
Capital Investments (in millions) (3) |
$ |
489 |
$ |
547 |
$ |
114 |
$ |
41 |
$ |
1,191 | ||||
Total Gross Producing Wells (4) |
983 |
364 |
4,191 |
20 |
5,558 | |||||||||
Total Net Producing Wells (4) |
516 |
255 |
2,921 |
17 |
3,709 | |||||||||
Total Net Acreage |
191,226 |
290,291 |
917,842 |
386,304 |
(5) |
1,785,663 | ||||||||
Net Undeveloped Acreage |
87,927 |
219,709 |
424,858 |
369,236 |
(5) |
1,101,730 | ||||||||
PV-10: |
||||||||||||||
Pre-Tax (in millions) (6) |
$ |
2,085 |
$ |
1,718 |
$ |
1,978 |
$ |
3 |
$ |
5,784 | ||||
PV of Taxes (in millions) (6) |
80 |
66 |
76 |
– |
222 | |||||||||
After-Tax (in millions) (6) |
$ |
2,005 |
$ |
1,652 |
$ |
1,902 |
$ |
3 |
$ |
5,562 | ||||
Percent of Total |
36% |
30% |
34% |
0% |
100% | |||||||||
Percent Operated (7) |
99% |
100% |
99% |
100% |
99% |
(1) |
Other consists primarily of properties in Canada, Colorado and Louisiana. |
(2) |
We have no reserves from synthetic gas, synthetic oil or nonrenewable natural resources intended to be upgraded into synthetic gas or oil. We used standard engineering and geoscience methods, or a combination of methodologies in determining estimates of material properties, including performance and test date analysis offset statistical analogy of performance data, volumetric evaluation, including analysis of petrophysical parameters (including porosity, net pay, fluid saturations (i.e., water, oil and gas) and permeability) in combination with estimated reservoir parameters (including reservoir temperature and pressure, formation depth and formation volume factors), geological analysis, including structure and isopach maps and seismic analysis, including review of 2-D and 3-D data to ascertain faults, closure and other factors. |
(3) |
Total and Other capital investments excludes $57 million related to our E&P service companies, of which $37 million related to water infrastructure. |
(4) |
Represents producing wells, including 400 wells in which we only have an overriding royalty interest in Northeast Appalachia, used in the December 31, 2017 reserves calculation. |
(5) |
Excludes exploration licenses for 2,518,519 net acres in New Brunswick, Canada, which have been subject to a moratorium since 2015. |
(6) |
Pre-tax PV-10 (a non-GAAP measure) is one measure of the value of a company's proved reserves that we believe is used by securities analysts to compare relative values among peer companies without regard to income taxes. The reconciling difference in pre-tax PV-10 and the after-tax PV-10, or standardized measure, is the discounted value of future income taxes on the estimated cash flows from our proved natural gas, oil and NGL reserves. |
(7) |
Based upon pre-tax PV-10 of proved developed producing activities. |
The Company's 2017 and three-year average proved developed finding and development (PD F&D) costs were $0.72 and $0.80 per Mcfe, respectively, when excluding the impact of capitalizing interest and portions of G&A costs in accordance with the full cost method of accounting.
Total Company PD F&D |
Three-Year | ||||||||||
12 Months Ended December 31, |
Total | ||||||||||
2017 |
2016 |
2015 |
2017 | ||||||||
Total PD Adds (Bcfe): |
|||||||||||
New PD adds |
1,258 |
257 |
416 |
1,931 | |||||||
PUD conversions |
46 |
220 |
1,044 |
1,310 | |||||||
Total PD Adds |
1,304 |
477 |
1,460 |
3,241 | |||||||
Costs Incurred (in millions): |
|||||||||||
Proved property acquisition costs |
$ |
– |
$ |
– |
$ |
81 |
$ |
81 | |||
Unproved property acquisition costs |
194 |
171 |
692 |
1,057 | |||||||
Exploration costs |
22 |
17 |
50 |
89 | |||||||
Development costs |
1,024 |
433 |
1,417 |
2,874 | |||||||
Capitalized Costs Incurred |
$ |
1,240 |
$ |
621 |
$ |
2,240 |
$ |
4,101 | |||
Subtract (in millions): |
|||||||||||
Proved property acquisition costs |
$ |
– |
$ |
– |
$ |
(81) |
$ |
(81) | |||
Unproved property acquisition costs |
(194) |
(171) |
(692) |
(1,057) | |||||||
Capitalized interest and expense(1) associated with development and exploration |
(103) |
(91) |
(187) |
(381) | |||||||
PD Costs Incurred |
$ |
943 |
$ |
359 |
$ |
1,280 |
$ |
2,582 | |||
PD F&D |
$ |
0.72 |
$ |
0.75 |
$ |
0.88 |
$ |
0.80 |
Note: Amounts may not add due to rounding | |
(1) |
Adjusting for the impacts of the full cost accounting method for comparability. |
Division PD F&D |
12 Months Ended December 31, 2017 | |||||||||||||
Appalachia |
Fayetteville |
|||||||||||||
Northeast |
Southwest |
Shale |
Other |
Total | ||||||||||
Total PD Adds (Bcfe): |
||||||||||||||
New PD adds |
790 |
419 |
48 |
1 |
1,258 | |||||||||
PUD conversions |
17 |
– |
29 |
– |
46 | |||||||||
Total PD Adds |
807 |
419 |
77 |
1 |
1,304 | |||||||||
Costs Incurred (in millions): |
||||||||||||||
Proved property acquisition costs |
$ |
– |
$ |
– |
$ |
– |
$ |
– |
$ |
– | ||||
Unproved property acquisition costs |
20 |
154 |
1 |
19 |
194 | |||||||||
Exploration costs |
8 |
3 |
– |
11 |
22 | |||||||||
Development costs |
471 |
402 |
125 |
26 |
1,024 | |||||||||
Capitalized Costs Incurred |
$ |
499 |
$ |
559 |
$ |
126 |
$ |
56 |
$ |
1,240 | ||||
Subtract (in millions): |
||||||||||||||
Proved property acquisition costs |
$ |
– |
$ |
– |
$ |
– |
$ |
– |
$ |
– | ||||
Unproved property acquisition costs |
(20) |
(154) |
(1) |
(19) |
(194) | |||||||||
Capitalized interest and expense(1) associated with development and exploration |
(36) |
(38) |
(18) |
(11) |
(103) | |||||||||
PD Costs Incurred |
$ |
443 |
$ |
367 |
$ |
107 |
$ |
26 |
$ |
943 | ||||
PD F&D |
$ |
0.55 |
$ |
0.88 |
$ |
1.39 |
$ |
– |
$ |
0.72 |
Note: Amounts may not add due to rounding | |
(1) |
Adjusting for the impacts of the full cost accounting method for comparability. |
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three and twelve months ended December 31, 2017 and December 31, 2016, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
Proved developed finding and development costs – Proved developed (PD) finding and development (F&D) costs are computed here by dividing exploration and development capital costs incurred, excluding capitalized interest and expenses, for the indicated period by PD reserve additions and proved undeveloped (PUD) conversions for that same period. At times, adjustments are made to this calculation in order to improve usefulness for investors. For example, adjustments are made to exclude the differences between accounting methods to improve comparability. The following computes PD F&D costs for the periods ending December 31, 2017, 2016 and 2015 and the three years ending December 31, 2017.
The Company believes that providing a measure of PD F&D costs is useful for investors as a means of evaluating a Company's cost to add proved reserves on a per thousand cubic feet of natural gas equivalent basis. These measures are provided in addition to, and not as an alternative for the financial statements, including the notes thereto, contained in Southwestern's Annual Report on Form 10-K. Due to various factors, including timing differences, PD F&D costs do not necessarily reflect precisely the costs associated with particular reserves. Changes in commodity prices can affect the magnitude of recorded increases in reserves independent of the related costs of such increases. As a result of the foregoing factors and various factors that could materially affect the timing and amounts of future increases in reserves and the timing and amounts of future costs, including factors disclosed in Southwestern's filings with the SEC, future PD F&D costs may differ materially from those set forth above. Further, the methods used by Southwestern to calculate its PD F&D costs may differ significantly from methods used by other companies to compute similar measures and, as a result, Southwestern's PD F&D costs may not be comparable to similar measures provided by other companies.
3 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net income (loss) attributable to common stock |
$ |
267 |
$ |
(237) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
31 |
(6) | |||
Impairment of natural gas and oil properties |
– |
– | |||
Restructuring and other one-time charges |
– |
12 | |||
Gain on sale of assets, net |
(1) |
– | |||
Loss on early extinguishment of debt and other bank fees |
3 |
– | |||
(Gain) loss on certain derivatives |
(101) |
324 | |||
Adjustments due to inventory valuation and other |
(1) |
– | |||
Loss on foreign currency adjustment |
6 |
– | |||
Adjustments due to discrete tax items(1) |
(176) |
74 | |||
Tax impact on adjustments |
35 |
(128) | |||
Adjusted net income attributable to common stock |
$ |
63 |
$ |
39 |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance. |
3 Months Ended December 31, | |||||
2017 |
2016 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted earnings (loss) per share |
$ |
0.53 |
$ |
(0.48) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
0.06 |
(0.01) | |||
Impairment of natural gas and oil properties |
– |
– | |||
Restructuring and other one-time charges |
– |
0.02 | |||
Gain on sale of assets, net |
(0.00) |
– | |||
Loss on early extinguishment of debt and other bank fees |
0.01 |
– | |||
(Gain) loss on certain derivatives |
(0.20) |
0.66 | |||
Adjustments due to inventory valuation and other |
(0.00) |
– | |||
Loss on foreign currency adjustment |
0.01 |
– | |||
Adjustments due to discrete tax items(1) |
(0.36) |
0.15 | |||
Tax impact on adjustments |
0.07 |
(0.26) | |||
Adjusted diluted earnings per share |
$ |
0.12 |
$ |
0.08 |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance. |
12 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net income (loss) attributable to common stock |
$ |
815 |
$ |
(2,751) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
90 |
– | |||
Impairment of natural gas and oil properties |
– |
2,321 | |||
Restructuring and other one-time charges |
– |
89 | |||
Gain on sale of assets, net |
(4) |
(3) | |||
Loss on early extinguishment of debt and other bank fees(1) |
73 |
57 | |||
Legal settlements |
5 |
– | |||
(Gain) loss on certain derivatives |
(451) |
373 | |||
Loss on foreign currency adjustment |
6 |
– | |||
Adjustments due to inventory valuation and other |
(2) |
3 | |||
Adjustments due to discrete tax items(2) |
(455) |
978 | |||
Tax impact on adjustments |
142 |
(1,074) | |||
Adjusted net income (loss) attributable to common stock |
$ |
219 |
$ |
(7) |
(1) |
2016 includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance. |
12 Months Ended December 31, | |||||
2017 |
2016 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted earnings (loss) per share |
$ |
1.63 |
$ |
(6.32) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
0.18 |
– | |||
Impairment of natural gas and oil properties |
– |
5.33 | |||
Restructuring and other one-time charges |
– |
0.20 | |||
Gain on sale of assets, net |
(0.01) |
(0.00) | |||
Loss on early extinguishment of debt and other bank fees(1) |
0.15 |
0.13 | |||
Legal settlements |
0.01 |
– | |||
(Gain) loss on certain derivatives |
(0.90) |
0.86 | |||
Loss on foreign currency adjustment |
0.01 |
– | |||
Adjustments due to inventory valuation and other |
(0.00) |
0.01 | |||
Adjustments due to discrete tax items(2) |
(0.91) |
2.25 | |||
Tax impact on adjustments |
0.28 |
(2.47) | |||
Adjusted diluted earnings (loss) per share |
$ |
0.44 |
$ |
(0.01) |
(1) |
Includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2018 income tax rate to be 24.5% before the impacts of any valuation allowance. |
3 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
308 |
$ |
161 | |
Add back: |
|||||
Changes in operating assets and liabilities |
14 |
49 | |||
Restructuring charges |
– |
1 | |||
Net cash flow |
$ |
322 |
$ |
211 | |
12 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
1,097 |
$ |
498 | |
Add back: |
|||||
Changes in operating assets and liabilities |
41 |
99 | |||
Restructuring charges |
– |
48 | |||
Net cash flow |
$ |
1,138 |
$ |
645 | |
3 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Operating income: |
|||||
Operating income |
$ |
167 |
$ |
122 | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
– | |||
Gain on sale of assets, net |
(1) |
– | |||
Loss on early extinguishment of debt and other bank fees |
3 |
– | |||
Restructuring and other one-time charges |
– |
12 | |||
Adjusted operating income |
$ |
169 |
$ |
134 | |
12 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating income (loss) |
$ |
731 |
$ |
(2,195) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
2,321 | |||
Gain on sale of assets, net |
(4) |
– | |||
Legal settlements |
5 |
– | |||
Loss on early extinguishment of debt and other bank fees |
3 |
– | |||
Restructuring and other one-time charges |
– |
89 | |||
Adjusted operating income |
$ |
735 |
$ |
215 | |
3 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
E&P segment operating income: |
|||||
E&P segment operating income |
$ |
114 |
$ |
82 | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
– | |||
Restructuring and other one-time charges |
– |
12 | |||
Loss on early extinguishment of debt and other bank fees |
3 |
– | |||
Adjusted E&P segment operating income |
$ |
117 |
$ |
94 | |
12 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
549 |
$ |
(2,404) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
2,321 | |||
Legal settlements |
5 |
– | |||
Loss on early extinguishment of debt and other bank fees |
3 |
– | |||
Restructuring and other one-time charges |
– |
86 | |||
Adjusted E&P segment operating income |
$ |
557 |
$ |
3 | |
December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
4,391 |
$ |
4,653 | |
Subtract: |
|||||
Cash and cash equivalents |
(916) |
(1,423) | |||
Net debt |
$ |
3,475 |
$ |
3,230 | |
12 Months Ended December 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
EBITDA: |
|||||
Net income (loss) |
$ |
1,046 |
$ |
(2,643) | |
Add back: |
|||||
Interest expense |
135 |
88 | |||
Income tax benefit |
(93) |
(29) | |||
Depreciation, depletion and amortization |
504 |
436 | |||
Impairment of natural gas and oil properties |
– |
2,321 | |||
Restructuring and other one-time charges |
– |
89 | |||
Gain on sale of assets, net |
(4) |
(3) | |||
Loss on early extinguishment of debt and other bank fees |
73 |
51 | |||
Legal settlements |
5 |
– | |||
(Gain) loss on certain derivatives |
(451) |
373 | |||
Loss on foreign currency adjustment |
6 |
– | |||
Adjustments due to inventory valuation and other |
(2) |
3 | |||
Stock based compensation expense |
28 |
35 | |||
Adjusted EBITDA |
$ |
1,247 |
$ |
721 |
Southwestern management will host a teleconference call on Friday, March 2, 2018 at 10:00 a.m. Eastern to discuss its fourth quarter and year-end 2017 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
Cautionary Note to U.S. Investors – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves. We use the term "EUR" in this release that the SEC's guidelines prohibit us from including in filings with the SEC. The quarterly reserves data included in this release are estimates we prepared that have not been audited by our independent reserve engineers. U.S. investors are urged to consider closely the oil and gas disclosures in our Form 10-K and other reports and filings with the SEC. Copies are available from the SEC and from the Southwestern Energy Company website.
OPERATING STATISTICS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the years ended | |||||||||||
December 31, |
December 31, | |||||||||||
2017 |
2016 |
2017 |
2016 | |||||||||
Exploration & Production |
||||||||||||
Production |
||||||||||||
Gas production (Bcf) |
210 |
183 |
797 |
788 | ||||||||
Oil production (MBbls) |
580 |
463 |
2,327 |
2,192 | ||||||||
NGL production (MBbls) |
4,111 |
2,792 |
14,245 |
12,372 | ||||||||
Total production (Bcfe) |
239 |
202 |
897 |
875 | ||||||||
Commodity Prices |
||||||||||||
Average realized gas price per Mcf, including derivatives |
$ |
2.12 |
$ |
2.07 |
$ |
2.19 |
$ |
1.64 | ||||
Average realized gas price per Mcf, excluding derivatives |
$ |
2.00 |
$ |
2.00 |
$ |
2.23 |
$ |
1.59 | ||||
Average realized oil price per Bbl |
$ |
48.05 |
$ |
41.18 |
$ |
43.12 |
$ |
31.20 | ||||
Average realized NGL price per Bbl, including derivatives |
$ |
17.98 |
$ |
12.08 |
$ |
14.48 |
$ |
7.46 | ||||
Average realized NGL price per Bbl, excluding derivatives |
$ |
17.97 |
$ |
12.08 |
$ |
14.46 |
$ |
7.46 | ||||
Summary of Derivative Activity in the Statement of Operations |
||||||||||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
25 |
$ |
14 |
$ |
(27) |
$ |
36 | ||||
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
100 |
$ |
(330) |
$ |
449 |
$ |
(375) | ||||
Average unit costs per Mcfe |
||||||||||||
Lease operating expenses |
$ |
0.91 |
$ |
0.87 |
$ |
0.90 |
$ |
0.87 | ||||
General & administrative expenses (1) |
$ |
0.22 |
$ |
0.27 |
$ |
0.22 |
$ |
0.22 | ||||
Taxes, other than income taxes (2) |
$ |
0.07 |
$ |
0.11 |
$ |
0.10 |
$ |
0.10 | ||||
Full cost pool amortization |
$ |
0.48 |
$ |
0.30 |
$ |
0.45 |
$ |
0.38 | ||||
Midstream |
||||||||||||
Volumes marketed (Bcfe) |
285 |
248 |
1,067 |
1,062 | ||||||||
Volumes gathered (Bcf) |
119 |
138 |
499 |
601 |
(1) |
Excludes $5 million of one-time legal charges for the year ended December 31, 2017. Excludes $12 million and $83 million of restructuring and other one-time charges for the three months and year ended December 31, 2016, respectively. |
(2) |
Excludes $3 million of restructuring charges for the year ended December 31, 2016. |
STATEMENTS OF OPERATIONS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the years ended | |||||||||||
December 31, |
December 31, | |||||||||||
2017 |
2016 |
2017 |
2016 | |||||||||
(in millions, except share/per share amounts) | ||||||||||||
Operating Revenues |
||||||||||||
Gas sales |
$ |
425 |
$ |
367 |
$ |
1,793 |
$ |
1,273 | ||||
Oil sales |
29 |
19 |
102 |
69 | ||||||||
NGL sales |
74 |
33 |
206 |
92 | ||||||||
Marketing |
236 |
233 |
972 |
864 | ||||||||
Gas gathering |
41 |
32 |
126 |
138 | ||||||||
Other |
4 |
– |
4 |
– | ||||||||
809 |
684 |
3,203 |
2,436 | |||||||||
Operating Costs and Expenses |
||||||||||||
Marketing purchases |
236 |
237 |
976 |
864 | ||||||||
Operating expenses |
190 |
137 |
671 |
592 | ||||||||
General and administrative expenses |
63 |
76 |
233 |
247 | ||||||||
Restructuring charges |
– |
1 |
– |
78 | ||||||||
Depreciation, depletion and amortization |
140 |
87 |
504 |
436 | ||||||||
Impairment of natural gas and oil properties |
– |
– |
– |
2,321 | ||||||||
Gain on sale of assets, net |
(6) |
– |
(6) |
– | ||||||||
Taxes, other than income taxes |
19 |
24 |
94 |
93 | ||||||||
642 |
562 |
2,472 |
4,631 | |||||||||
Operating Income (Loss) |
167 |
122 |
731 |
(2,195) | ||||||||
Interest Expense |
||||||||||||
Interest on debt |
64 |
58 |
239 |
226 | ||||||||
Other interest charges |
2 |
2 |
9 |
14 | ||||||||
Interest capitalized |
(28) |
(29) |
(113) |
(152) | ||||||||
38 |
31 |
135 |
88 | |||||||||
Gain (Loss) on Derivatives |
127 |
(311) |
422 |
(339) | ||||||||
Loss on Early Extinguishment of Debt |
– |
– |
(70) |
(51) | ||||||||
Other Income, Net |
(1) |
1 |
5 |
1 | ||||||||
Income (Loss) Before Income Taxes |
255 |
(219) |
953 |
(2,672) | ||||||||
Benefit for Income Taxes |
||||||||||||
Current |
(12) |
(7) |
(22) |
(7) | ||||||||
Deferred |
(67) |
(2) |
(71) |
(22) | ||||||||
(79) |
(9) |
(93) |
(29) | |||||||||
Net Income (Loss) |
334 |
(210) |
1,046 |
(2,643) | ||||||||
Mandatory convertible preferred stock dividend |
27 |
27 |
108 |
108 | ||||||||
Participating securities - mandatory convertible preferred stock |
40 |
– |
123 |
– | ||||||||
Net Income (Loss) Attributable to Common Stock |
$ |
267 |
$ |
(237) |
$ |
815 |
$ |
(2,751) | ||||
Income (Loss) Per Common Share |
||||||||||||
Basic |
$ |
0.53 |
$ |
(0.48) |
$ |
1.64 |
$ |
(6.32) | ||||
Diluted |
$ |
0.53 |
$ |
(0.48) |
$ |
1.63 |
$ |
(6.32) | ||||
Weighted Average Common Shares Outstanding | ||||||||||||
Basic |
503,614,377 |
489,287,827 |
498,264,321 |
435,337,402 | ||||||||
Diluted |
507,137,867 |
489,287,827 |
500,804,297 |
435,337,402 |
BALANCE SHEETS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
December 31, |
December 31, | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,509 |
$ |
1,872 | ||
Property and equipment |
25,769 |
24,489 | ||||
Less: Accumulated depreciation, depletion and amortization |
(19,997) |
(19,534) | ||||
Total property and equipment, net |
5,772 |
4,955 | ||||
Other long-term assets |
240 |
249 | ||||
Total assets |
$ |
7,521 |
$ |
7,076 | ||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
$ |
780 |
$ |
1,064 | ||
Long-term debt |
4,391 |
4,612 | ||||
Pension and other postretirement liabilities |
58 |
49 | ||||
Other long-term liabilities |
313 |
434 | ||||
Total liabilities |
5,542 |
6,159 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 512,134,311 shares as of December 31, 2017 and 495,248,369 as of December 31, 2016 |
5 |
5 | ||||
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of December 31, 2017 and 2016, converted to common stock in January 2018 |
– |
– | ||||
Additional paid-in capital to common stock |
4,698 |
4,677 | ||||
Accumulated deficit |
(2,679) |
(3,725) | ||||
Accumulated other comprehensive loss |
(44) |
(39) | ||||
Common stock in treasury; 31,269 shares as of December 31, 2017 and 2016 |
(1) |
(1) | ||||
Total equity |
1,979 |
917 | ||||
Total liabilities and equity |
$ |
7,521 |
$ |
7,076 |
STATEMENTS OF CASH FLOWS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
For the years ended | ||||||
December 31, | ||||||
2017 |
2016 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities: |
||||||
Net income (loss) |
$ |
1,046 |
$ |
(2,643) | ||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
||||||
Depreciation, depletion and amortization |
504 |
436 | ||||
Impairment of natural gas and oil properties |
– |
2,321 | ||||
Amortization of debt issuance costs |
9 |
14 | ||||
Deferred income taxes |
(71) |
(22) | ||||
(Gain) loss on derivatives, net of settlement |
(451) |
373 | ||||
Stock-based compensation |
24 |
29 | ||||
Gain on sales of assets, net |
(6) |
– | ||||
Restructuring charges |
– |
30 | ||||
Loss on early extinguishment of debt |
70 |
51 | ||||
Other |
13 |
8 | ||||
Change in assets and liabilities |
(41) |
(99) | ||||
Net cash provided by operating activities |
1,097 |
498 | ||||
Cash Flows From Investing Activities: |
||||||
Capital investments |
(1,268) |
(593) | ||||
Proceeds from sale of property and equipment |
10 |
430 | ||||
Other |
6 |
1 | ||||
Net cash used in investing activities |
(1,252) |
(162) | ||||
Cash Flows From Financing Activities: |
||||||
Payments on current portion of long-term debt |
(328) |
(1) | ||||
Payments on long-term debt |
(1,139) |
(1,175) | ||||
Payments on revolving credit facility |
– |
(3,268) | ||||
Borrowings under revolving credit facility |
– |
3,152 | ||||
Payments on commercial paper |
– |
(242) | ||||
Borrowings under commercial paper |
– |
242 | ||||
Change in bank drafts outstanding |
9 |
(20) | ||||
Proceeds from issuance of long-term debt |
1,150 |
1,191 | ||||
Payment of debt issuance costs |
(24) |
(17) | ||||
Proceeds from issuance of common stock |
– |
1,247 | ||||
Preferred stock dividend |
(16) |
(27) | ||||
Cash paid for tax withholding |
(2) |
(9) | ||||
Other |
(2) |
(1) | ||||
Net cash provided by (used in) financing activities |
(352) |
1,072 | ||||
Increase (decrease) in cash and cash equivalents |
(507) |
1,408 | ||||
Cash and cash equivalents at beginning of year |
1,423 |
15 | ||||
Cash and cash equivalents at end of year |
$ |
916 |
$ |
1,423 |
SEGMENT INFORMATION (Unaudited) |
|||||||||||||||
Southwestern Energy Company and Subsidiaries |
Exploration |
||||||||||||||
and |
Midstream |
||||||||||||||
(in millions) |
Production |
Services |
Other |
Eliminations |
Total | ||||||||||
Three months ended December 31, 2017 |
|||||||||||||||
Revenues |
$ |
527 |
$ |
784 |
$ |
– |
$ |
(502) |
$ |
809 | |||||
Marketing purchases |
– |
683 |
– |
(447) |
236 | ||||||||||
Operating expenses |
218 |
24 |
– |
(55) |
187 | ||||||||||
General and administrative expenses |
55 |
8 |
– |
– |
63 | ||||||||||
Depreciation, depletion and amortization |
123 |
17 |
– |
– |
140 | ||||||||||
Taxes, other than income taxes |
17 |
1 |
1 |
– |
19 | ||||||||||
Gain on sale of assets, net |
– |
(3) |
– |
– |
(3) | ||||||||||
Operating income (loss) |
114 |
54 |
(1) |
– |
167 | ||||||||||
Capital investments(1) |
327 |
11 |
9 |
– |
347 | ||||||||||
Three months ended December 31, 2016 |
|||||||||||||||
Revenues |
$ |
415 |
$ |
707 |
$ |
– |
$ |
(438) |
$ |
684 | |||||
Marketing purchases |
– |
612 |
– |
(375) |
237 | ||||||||||
Operating expenses |
175 |
25 |
– |
(63) |
137 | ||||||||||
General and administrative expenses |
63 |
13 |
– |
– |
76 | ||||||||||
Restructuring charges |
1 |
– |
– |
– |
1 | ||||||||||
Depreciation, depletion and amortization |
71 |
16 |
– |
– |
87 | ||||||||||
Taxes, other than income taxes |
23 |
1 |
– |
– |
24 | ||||||||||
Operating income |
82 |
40 |
– |
– |
122 | ||||||||||
Capital investments(1) |
251 |
18 |
3 |
– |
272 | ||||||||||
Twelve months ended December 31, 2017 |
|||||||||||||||
Revenues |
$ |
2,086 |
$ |
3,198 |
$ |
– |
$ |
(2,081) |
$ |
3,203 | |||||
Marketing purchases |
– |
2,824 |
– |
(1,848) |
976 | ||||||||||
Operating expenses |
809 |
95 |
– |
(233) |
671 | ||||||||||
General and administrative expenses |
202 |
31 |
– |
– |
233 | ||||||||||
Depreciation, depletion and amortization |
440 |
64 |
– |
– |
504 | ||||||||||
Gain on sale of asset, net |
– |
(6) |
– |
– |
(6) | ||||||||||
Taxes, other than income taxes |
86 |
7 |
1 |
– |
94 | ||||||||||
Operating income (loss) |
549 |
183 |
(1) |
– |
731 | ||||||||||
Capital investments(1) |
1,248 |
32 |
13 |
– |
1,293 | ||||||||||
Twelve months ended December 31, 2016 |
|||||||||||||||
Revenues |
$ |
1,413 |
$ |
2,569 |
$ |
– |
$ |
(1,546) |
$ |
2,436 | |||||
Marketing purchases |
– |
2,145 |
– |
(1,281) |
864 | ||||||||||
Operating expenses |
761 |
96 |
– |
(265) |
592 | ||||||||||
General and administrative expenses |
204 |
43 |
– |
– |
247 | ||||||||||
Restructuring charges |
75 |
3 |
– |
– |
78 | ||||||||||
Depreciation, depletion and amortization |
371 |
65 |
– |
– |
436 | ||||||||||
Impairment of natural gas and oil properties |
2,321 |
– |
– |
– |
2,321 | ||||||||||
Taxes, other than income taxes |
85 |
8 |
– |
– |
93 | ||||||||||
Operating income (loss) |
(2,404) |
209 |
– |
– |
(2,195) | ||||||||||
Capital investments(1) |
623 |
21 |
4 |
– |
648 |
(1) |
Capital investments includes increases of $13 million and $67 million for the three months ended December 31, 2017 and 2016, respectively, and an increase of $43 million for the year ended December 31, 2016 relating to the change in accrued expenditures between periods. There was no impact to the year ended December 31, 2017. |
View original content with multimedia:http://www.prnewswire.com/news-releases/southwestern-energy-announces-2017-operational-and-financial-results-300607044.html
SOURCE Southwestern Energy Company
HOUSTON, Feb. 26, 2018 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that Julian Bott is joining the company as Executive Vice President and will become Chief Financial Officer on March 5, 2018. Jennifer Stewart, who has served as CFO on an interim basis, will become Senior Vice President, Government and Regulatory Affairs.
The Company also announced that it has named Michael Hancock as Vice President, Financial Planning and Analysis. This role will leverage the valuable perspective Michael gained in Investor Relations to enhance internal financial and operational analysis to shape strategy and drive additional shareholder value. Paige Penchas joins Southwestern as Vice President, Investor Relations to replace Michael.
"We welcome Julian and Paige to Southwestern Energy," said Bill Way, President and Chief Executive Officer. "We are fortunate to have the addition of their collective expertise as we reposition the Company to accelerate value from our highest return assets, strengthen our balance sheet and enhance our financial performance. I want to thank Jennifer and Michael for their exceptional work and congratulate them on their new roles in the Company."
About Julian Bott
Mr. Bott joins Southwestern Energy from SandRidge Energy, where he served as Chief Financial Officer since 2015. Throughout his career of various leadership positions, Mr. Bott has gained extensive experience in both finance and the capital markets and has built strong relationships throughout the energy and investment banking industries. Prior to SandRidge Energy, he served as Chief Financial Officer at Texas American Resources and 3DMD Technologies and as Managing Partner at Kensington Energy Partners. Earlier in his career, he held executive positions at the Toronto Dominion Bank and Bankers Trust Company. Mr. Bott holds a bachelor's degree in economics from Harvard University and an MBA from Rice University.
About Paige Penchas
Ms. Penchas has more than 20 years of experience in investor relations, treasury and financial services in the energy industry. She most recently served as Executive Vice President at The Abernathy MacGregor Group. Prior experience includes Managing Director, Institutional Sales at Tudor, Pickering, Holt, Treasurer of Nuevo Energy, Treasurer of Weatherford International and Investor Relations Director, Weatherford Enterra. Ms. Penchas began her energy career at Bank of America and holds a bachelor's degree in finance from the University of Texas and an MBA from Texas A&M University.
About Southwestern Energy
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-senior-leadership-changes-300603843.html
SOURCE Southwestern Energy Company
HOUSTON, Feb. 19, 2018 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2017 Fourth Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, March 2, 2018, at 10:00 a.m. EST with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Fourth Quarter 2017 Earnings |
When: |
March 2, 2018 @ 10:00 a.m. EST |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the |
If you are unable to participate during the live Webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
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SOURCE Southwestern Energy Company
HOUSTON, Dec. 18, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that an authorized committee of its Board of Directors declared a quarterly dividend of $15.625 per share on its 6.25% Series B Mandatory Convertible Preferred Stock, payable on January 16, 2018, to holders of record on January 1, 2018. This equates to $0.78125 for each depositary share, which represents a 1/20th interest in a share of the Series B preferred stock. The dividend is for the period beginning on October 15, 2017 and ending on January 14, 2018. The company has elected to pay this dividend in cash.
As of 5:00 p.m. New York time on January 12, 2018, each share of the Company's 6.25% Series B Mandatory Convertible Preferred Stock will automatically convert into 43.4782 common shares, entitling the holders of depositary shares to receive 2.17391 shares of common stock per depositary share (subject to adjustment if the volume weighted average price of the company's common stock is above $23.00 per share for the period beginning on December 11, 2017 and ending on January 9, 2018). The conversion is expected to result in the issuance of approximately 75.0 million additional shares of common stock. Additional details on the conversion rate can be found in the Certificate of Designations (link below).
https://www.sec.gov/Archives/edgar/data/7332/000119312515016320/d854968dex31.htm
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-declares-dividend-on-mandatory-convertible-preferred-stock-and-provides-update-on-final-conversion-amount-300572793.html
SOURCE Southwestern Energy Company
HOUSTON, Dec. 4, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE:SWN) today announced that, effective December 5, 2017, Clayton A. Carrell will join the company as its Executive Vice President and Chief Operating Officer, responsible for the Company's operational and technical activities.
"We are excited to be adding another integral member of the leadership team as we execute our strategy and position the Company for the future," said Bill Way, President and Chief Executive Officer of Southwestern Energy. "Clay has vast operating and leadership experience from various engineering and management roles throughout his career. He has a proven track record of delivering operational and technical excellence, and we are confident that he will further enhance Southwestern's already leading operating capabilities. We identified Clay during a thorough search process and are looking forward to working with him as we continue to deliver value to our shareholders."
Mr. Carrell joins Southwestern Energy from EP Energy, where he served as Executive Vice President and Chief Operating Officer since 2012. He joined El Paso Corporation in 2007, where he held various executive leadership roles and helped establish EP Energy as an independent company before being named Chief Operating Officer. Previously, Mr. Carrell was Vice President, Engineering & Operations at Peoples Energy Production from February 2001 to March 2007. Prior to joining Peoples Energy Production, Mr. Carrell worked at Burlington Resources and ARCO Oil and Gas Company from May 1988 to February 2001.
"I am eager to join Southwestern Energy and to lead the operations across its high-quality asset base," said Mr. Carrell. "I look forward to working closely with Bill and the rest of the team to further deliver value for Southwestern Energy and its shareholders."
Mr. Carrell serves on the Industry Board of the Texas A&M Petroleum Engineering Department and is a member of the Society of Petroleum Engineers. Mr. Carrell is also a member of the Board of Trustees of the Center for Hearing and Speech in Houston, Texas.
About Southwestern Energy
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-appoints-clayton-carrell-as-chief-operating-officer-300566172.html
SOURCE Southwestern Energy Company
HOUSTON, Nov. 29, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced that, in connection with its previously announced consent solicitations (the "Consent Solicitations") with respect to the Company's 4.10% Senior Notes due 2022 (the "2022 Notes") and 4.95% Senior Notes due 2025 (the "2025 Notes" and, together with the 2022 Notes, the "Notes"), the Company has received the consents ("Consents") from holders of at least a majority of the outstanding principal amount of each of the 2022 Notes and 2025 Notes (the "Requisite Consents"), respectively, to, among other things, amend certain restrictive covenants (the "Proposed Amendments") contained in the indentures governing the 2022 Notes and 2025 notes (each an "Indenture"), subject to the terms and conditions described in the Consent Solicitation Statement dated November 21, 2017 (the "Consent Solicitation Statement"). The Consent Solicitations expired at 5:00 p.m., New York City time, on November 28, 2017 (the "Expiration Date").
Accordingly, the Company expects to execute a supplemental indenture with the applicable trustee (each, a "Supplemental Indenture") to the applicable Indenture, effecting the Proposed Amendments with respect to each series of Notes. Although a Supplemental Indenture will become effective immediately upon execution, the Proposed Amendments will become operative only upon the payment by the Company of the aggregate cash payment equal to $5.00 per $1,000 principal amount of Notes (the "Consent Payment") to D.F. King & Co., Inc., as paying agent, on behalf of the holders who delivered valid and unrevoked Consents to the Proposed Amendments with respect to the applicable series of Notes on or prior to the Expiration Date. The Company expects to make the Consent Payment on or around November 30, 2017. The Company's obligation to accept and pay holders the Consent Payment for valid and unrevoked Consents to the Proposed Amendments with respect to the applicable series of Notes is subject to the terms and conditions described in the Consent Solicitation Statement.
Citigroup Global Markets Inc. is the Lead Solicitation Agent, and Credit Agricole Securities (USA) Inc. and MUFG Securities Americas Inc. are the Solicitation Agents. D.F. King & Co., Inc. has been retained to serve as the Information, Tabulation and Paying Agent for the Consent Solicitations. Persons with questions regarding the Consent Solicitations should contact Citigroup Global Markets Inc. at (toll free) (800) 558-3745 or (New York) (212) 723-6106; Credit Agricole Securities (USA) Inc. at (toll free) (866) 807-6030 or (collect) (212) 261-7802; or MUFG Securities Americas Inc. at (toll free) (877) 744-4532 or (collect) (212) 405-7481. Requests for the Consent Solicitation Statement should be directed to D.F. King & Co., Inc. at (toll free) (866) 406-2283 or by email to swn@dfking.com.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing.
Forward-Looking Statements
This news release contains forward-looking statements. Forward-looking statements relate to future events, the Consent Solicitations 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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-receipt-of-requisite-consents-in-its-consent-solicitations-related-to-senior-notes-300563259.html
SOURCE Southwestern Energy Company
HOUSTON, Nov. 21, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced that it is soliciting consents (the "Consent Solicitations") from holders of its outstanding senior notes listed in the table below (the "Notes") to proposed amendments to the indentures (the "Indentures") relating to such Notes.
Title of Notes |
CUSIP Number |
Aggregate Principal |
Consent Payment per U.S. $1,000 |
4.10% Senior Notes due 2022 |
845467AF6; |
$1,000,000,000 |
$5.00 |
4.95% Senior Notes due 2025(1) |
845467AL3 |
$1,000,000,000 |
$5.00 |
(1) |
In February and June 2016, Moody's and S&P downgraded certain senior notes of the Company, increasing the interest rates by 175 basis points effective July 2016. As a result of downgrades, the interest rate increased to 6.70% for the 2025 Notes. |
The Consent Solicitations are being made solely upon the terms and conditions described in the Company's Consent Solicitation Statement dated November 21, 2017 (the "Consent Solicitation Statement"). Full details on the terms and conditions of the Consent Solicitations are set forth in the Consent Solicitation Statement.
The Company is soliciting consents ("Consents") from the holders of the 4.10% Senior Notes due 2022 (the "2022 Notes") and the 4.95% Senior Notes due 2025 (the "2025 Notes") for certain proposed amendments that would, among other things, amend certain restrictive covenants contained in the Indentures governing the 2022 Notes and 2025 notes (the "Proposed Amendments"). These amendments would conform the provisions of the supplemental indentures for the Notes to the parallel provisions of the supplemental indentures governing all other series of senior notes, other than the Notes, issued by the Company and currently outstanding, including the Company's 4.05% Senior Notes due 2020 and its recently issued 7.500% Senior Notes due 2026 and 7.750% Senior Notes due 2027.
Adoption of the Proposed Amendments with respect to each of the 2022 Notes and 2025 Notes requires the consent of the holders of at least a majority of the outstanding principal amount of the 2022 Notes and 2025 notes, respectively (the "Requisite Consents"). In the event that the Company receives the Requisite Consents on or prior to the expiration date (as defined below), the Company will pay an aggregate cash payment equal to $5.00 per $1,000 principal amount of Notes for which the Requisite Consents are validly delivered and unrevoked (the "Consent Payment") to the holders who delivered such valid and unrevoked Consents on or prior to the expiration date. No accrued interest will be paid on the Consent Payment. If the Proposed Amendments become operative with respect to the 2022 Notes or 2025 Notes, holders of the 2022 Notes or 2025 notes, as applicable, that do not deliver valid and unrevoked Consents with respect to their 2022 Notes or 2025 Notes, as applicable, prior to the expiration date, or at all, will be bound by the Proposed Amendments, meaning that the 2022 Notes or 2025 Notes, as applicable, will no longer have the benefit of the existing terms of certain covenants contained in the applicable Indenture. In addition, such holders will not receive the Consent Payment.
The Consent Solicitations are subject to, and conditioned upon, the satisfaction or waiver of certain conditions described in the Consent Solicitation Statement, including the receipt of the Requisite Consents.
The Consent Solicitations will expire at 5:00 p.m., New York City time, on November 28, 2017, unless extended or earlier terminated by the Company for either or both series of Notes (the "expiration date").
The Company intends to fund the Consent Solicitations, including fees and expenses payable in connection with the Consent Solicitations, with cash on hand.
Citigroup Global Markets Inc. is the Lead Solicitation Agent, and Credit Agricole Securities (USA) Inc. and MUFG Securities Americas Inc. are the Solicitation Agents. D.F. King & Co., Inc. has been retained to serve as the Information, Tabulation and Paying Agent for the Consent Solicitations. Persons with questions regarding the Consent Solicitations should contact Citigroup Global Markets Inc. at (toll free) (800) 558-3745 or (New York) (212) 723-6106; Credit Agricole Securities (USA) Inc. at (toll free) (866) 807-6030 or (collect) (212) 261-7802; or MUFG Securities Americas Inc. at (toll free) (877) 744-4532 or (collect) (212) 405-7481. Requests for the Consent Solicitation Statement should be directed to D.F. King & Co., Inc. at (toll free) (866) 406-2283 or by email to swn@dfking.com.
None of the Company, the Lead Solicitation Agent, the Solicitation Agents, the Information, Tabulation and Paying Agent, the trustees under the indentures governing the Notes or any of their respective affiliates is making any recommendation as to whether holders should deliver Consents in response to the Consent Solicitations. Holders must make their own decision as to whether to participate in the Consent Solicitations, and, if so, the principal amount of Notes in respect of which to deliver Consents.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Consent Solicitations are being made only pursuant to the Consent Solicitation Statement and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Consent Solicitations are required to be made by a licensed broker or dealer, the Consent Solicitations will be deemed to be made on behalf of the Company by the Lead Solicitation Agent and the Solicitation Agents, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-consent-solicitations-related-to-senior-notes-300559801.html
SOURCE Southwestern Energy Company
HOUSTON, Oct. 26, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the quarter ended September 30, 2017, along with other recent developments. Highlights include:
"The execution of our strategy continued to deliver strong results in the third quarter," said Bill Way, President and Chief Executive Officer of Southwestern Energy. "Through technological advancements, strategic negotiation of transportation, processing and gathering agreements, and improving our debt maturity schedule, we are driving material shareholder value and positioning ourselves for additional value creation in 2018 and beyond."
Financial Results |
For the three months ended |
For the nine months ended | |||||||||
September 30, |
September 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
(in millions, except per share amounts) |
|||||||||||
Operating income (loss) |
$ |
110 |
$ |
(725) |
$ |
564 |
$ |
(2,317) | |||
Adjusted operating income (non-GAAP measure) |
$ |
112 |
$ |
94 |
$ |
566 |
$ |
81 | |||
Net income (loss) attributable to common stock |
$ |
43 |
$ |
(735) |
$ |
548 |
$ |
(2,514) | |||
Adjusted net income (loss) attributable to common stock (non-GAAP measure) |
$ |
29 |
$ |
12 |
$ |
156 |
$ |
(52) | |||
Diluted earnings (loss) per share |
$ |
0.09 |
$ |
(1.52) |
$ |
1.10 |
$ |
(6.02) | |||
Adjusted diluted earnings (loss) per share (non-GAAP measure) |
$ |
0.06 |
$ |
0.03 |
$ |
0.31 |
$ |
(0.12) | |||
Net cash provided by operating activities |
$ |
211 |
$ |
172 |
$ |
789 |
$ |
337 | |||
Net cash flow (non-GAAP measure) |
$ |
248 |
$ |
173 |
$ |
816 |
$ |
434 | |||
Exploration and Production Operating Results |
For the three months ended |
For the nine months ended | |||||||||
September 30, |
September 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Production |
|||||||||||
Fayetteville (Bcf) |
78 |
90 |
241 |
289 | |||||||
Northeast Appalachia (Bcf) |
101 |
84 |
285 |
268 | |||||||
Southwest Appalachia (Bcfe) |
52 |
37 |
131 |
115 | |||||||
Other (Bcfe) |
1 |
– |
1 |
1 | |||||||
Total production (Bcfe) |
232 |
211 |
658 |
673 | |||||||
% Natural Gas |
88% |
90% |
89% |
90% | |||||||
Average unit costs per Mcfe |
|||||||||||
Lease operating expenses |
$ |
0.91 |
$ |
0.86 |
$ |
0.90 |
$ |
0.87 | |||
General & administrative expenses(1) |
$ |
0.23 |
$ |
0.23 |
$ |
0.22 |
$ |
0.21 | |||
Taxes, other than income taxes(2) |
$ |
0.10 |
$ |
0.10 |
$ |
0.10 |
$ |
0.09 | |||
Full cost pool amortization |
$ |
0.48 |
$ |
0.35 |
$ |
0.44 |
$ |
0.40 |
(1) |
Excludes $2 million and $71 million of restructuring charges for the three and nine months ended September 30, 2016, respectively. |
(2) |
Excludes $3 million of restructuring charges for the nine months ended September 30, 2016. |
Realized Prices |
For the three months ended |
For the nine months ended | |||||||||
September 30, |
September 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Natural Gas Price: |
|||||||||||
NYMEX Henry Hub Price ($/MMBtu)(1) |
$ |
3.00 |
$ |
2.81 |
$ |
3.17 |
$ |
2.29 | |||
Discount to NYMEX(2) |
(1.11) |
(1.03) |
(0.86) |
(0.82) | |||||||
Average realized gas price per Mcf, excluding hedges |
$ |
1.89 |
$ |
1.78 |
$ |
2.31 |
$ |
1.47 | |||
Gain (loss) on settled financial basis derivatives ($/Mcf) |
0.05 |
0.00 |
(0.04) |
0.01 | |||||||
Gain (loss) on settled commodity derivatives ($/Mcf) |
0.03 |
(0.05) |
(0.05) |
0.03 | |||||||
Average realized gas price per Mcf, including hedges |
$ |
1.97 |
$ |
1.73 |
$ |
2.22 |
$ |
1.51 | |||
Oil Price: |
|||||||||||
WTI oil price ($/Bbl) |
$ |
48.22 |
$ |
44.94 |
$ |
49.47 |
$ |
41.33 | |||
Discount to WTI |
(7.73) |
(9.53) |
(7.99) |
(12.80) | |||||||
Average oil price per Bbl |
$ |
40.49 |
$ |
35.41 |
$ |
41.48 |
$ |
28.53 | |||
NGL Price: |
|||||||||||
Average net realized NGL price per Bbl(3) |
$ |
14.47 |
$ |
7.04 |
$ |
13.06 |
$ |
6.11 | |||
Percentage of WTI |
30% |
16% |
26% |
15% |
(1) |
Based on last day settlement prices from monthly futures contracts. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
(3) |
Includes the impact of transportation costs and $0.02 per Bbl of realized hedge gains for the three and nine months ended September 30, 2017 and $0.01 per Bbl of realized hedge gains for the three months ended September 30, 2016. |
Third Quarter of 2017 Financial Results
E&P Segment – The operating income for the segment improved to $64 million for the third quarter of 2017, compared to an operating loss of $777 million during the third quarter of 2016 that included an $817 million impairment of natural gas and oil properties during this period last year. The increase in operating income was primarily due to the absence of impairments and restructuring charges and higher realized natural gas and liquids pricing, partially offset by higher operating costs.
Midstream Segment – Operating income for the segment, comprised of gathering and marketing activities, was $46 million for the third quarter of 2017, which included a $3 million gain on sale of equipment, compared to $52 million for the same period in 2016. The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale.
First Nine Months of 2017 Financial Results
E&P Segment – The operating income for the segment improved to $435 million for the first nine months of 2017, compared to an operating loss of $2.5 billion during the first nine months of 2016, which was primarily due to the $2.3 billion impairment of natural gas and oil properties and $74 million in restructuring charges during this period last year. The increase in operating income in 2017 was primarily due to the absence of impairments and restructuring charges and higher realized natural gas and liquids pricing, partially offset by higher operating costs.
Midstream Segment – Operating income for the segment, comprised of gathering and marketing activities, was $129 million for the first nine months of 2017, which included a $3 million gain on sale of equipment, compared to $169 million for the same period in 2016, which included $3 million in restructuring charges. The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale.
Capital Structure and Investments – At September 30, 2017, the Company had total debt of approximately $4.4 billion and $3.4 billion in net debt. In the third quarter, the Company completed a public offering of $650 million aggregate principal of its 7.50% senior notes due 2026 and $500 million aggregate principal of its 7.75% senior notes due 2027. The proceeds from this offering were used to repay $758 million of the Company's 2020 Notes and to repay the outstanding balance of $327 million on the Company's 2015 Term Loan. The Company now has only $92 million in bonds due prior to 2022. The undrawn revolver and the cash maintained on the balance sheet anchor the strong liquidity position the Company has built and intends to maintain as part of its disciplined financial plan.
During the first nine months of 2017, Southwestern invested a total of $946 million. This included approximately $921 million invested in its E&P business, $21 million invested in its Midstream segment and $4 million invested for corporate and other purposes. Of the $946 million, approximately $85 million was associated with capitalized interest and $77 million was associated with capitalized expenses.
Hedging Update
As of October 24, 2017, the Company had approximately 139 Bcf of its remaining 2017 forecasted gas production protected at an average swap or purchased put strike price of $3.01 per Mcf. Additionally, the Company had approximately 473 Bcf of its 2018 forecasted gas production protected at an average swap or purchased put strike price of $2.99 per Mcf, with upside exposure on approximately 62%, or 295 Bcf, of those protected volumes up to $3.39 per Mcf. The Company also had approximately 165 Bcf of its 2019 forecasted gas production protected at an average purchased put strike price or average swap price of $2.97 with upside exposure on approximately 66%, or 108 Bcf, of those protected volumes up to $3.32 per Mcf.
A detailed breakdown of the Company's natural gas derivative financial instruments as of October 24, 2017 is shown below. Please refer to the Company's 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 |
Swaps |
Sold Puts |
Purchased |
Sold Calls | |||||||||
Financial protection on production |
|||||||||||||
2017 |
|||||||||||||
Fixed price swaps |
73 |
$ |
3.06 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
32 |
– |
– |
2.96 |
3.38 | ||||||||
Three-way costless collars |
34 |
– |
2.29 |
2.97 |
3.30 | ||||||||
Total |
139 |
||||||||||||
2018 |
|||||||||||||
Fixed price swaps |
178 |
$ |
3.02 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
23 |
– |
– |
2.97 |
3.56 | ||||||||
Three-way costless collars |
272 |
– |
2.40 |
2.97 |
3.37 | ||||||||
Total |
473 |
||||||||||||
2019 |
|||||||||||||
Fixed price swaps |
57 |
$ |
3.01 |
$ |
– |
$ |
– |
$ |
– | ||||
Three-way costless collars |
108 |
$ |
– |
$ |
2.50 |
$ |
2.95 |
$ |
3.32 | ||||
Total |
165 |
||||||||||||
Sold call options |
|||||||||||||
2017 |
22 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.68 | ||||
2018 |
63 |
– |
– |
– |
3.50 | ||||||||
2019 |
52 |
– |
– |
– |
3.50 | ||||||||
2020 |
54 |
– |
– |
– |
3.65 | ||||||||
2021 |
35 |
– |
– |
– |
3.51 | ||||||||
Total |
225 |
Note: Amounts may not sum due to rounding |
As of October 24, 2017, the Company had also taken steps to mitigate the volatility of basis differentials by protecting basis on approximately 127 Bcf of its remaining 2017 forecasted natural gas production and 224 Bcf of its 2018 forecasted natural gas production at a basis differential to NYMEX natural gas prices of approximately ($0.53) per Mcf and ($0.29) per Mcf, respectively, which includes the impact of both physical and financial basis positions. A detailed breakdown of the Company's financial basis positions as of October 24, 2017 is shown below:
Financial basis positions (excludes physical positions) |
Volume (Bcf) |
Basis Differential ($/MMBTU) | |||
2017 |
|||||
Dominion South |
22.1 |
$ |
(1.16) | ||
TETCO M3 |
10.2 |
(0.48) | |||
Transco Z6 Non-NY |
0.3 |
0.47 | |||
Total |
32.6 |
$ |
(0.93) | ||
2018 |
|||||
Dominion South |
18.5 |
$ |
(1.17) | ||
TETCO M3 |
7.3 |
1.08 | |||
Transco Z6 Non-NY |
0.5 |
2.04 | |||
Total |
26.2 |
$ |
(0.49) |
E&P Operational Review
During the third quarter of 2017, Southwestern invested a total of approximately $320 million in the E&P business and participated in drilling 47 wells, completed 29 wells, and placed 37 wells to sales.
Three Months Ended Sept 30, 2017 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) (1) |
101 |
52 |
78 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
104 |
$ |
90 |
$ |
20 | ||
Acquisition and leasehold |
3 |
15 |
1 | |||||
Seismic and other |
4 |
2 |
5 | |||||
Capitalized interest and expense |
11 |
33 |
5 | |||||
Total capital investments |
$ |
122 |
$ |
140 |
$ |
31 | ||
Gross operated well count summary |
||||||||
Drilled |
23 |
20 |
4 | |||||
Completed |
18 |
7 |
4 | |||||
Wells to sales |
15 |
18 |
3 | |||||
Realized Price |
||||||||
NYMEX Henry Hub Price ($/MMBtu) |
$ |
3.00 |
$ |
3.00 |
$ |
3.00 | ||
Discount to NYMEX ($/Mcf)(2) |
$ |
(1.39) |
$ |
(1.01) |
$ |
(0.77) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
1.61 |
$ |
1.99 |
$ |
2.23 |
(1) |
Southwest Appalachia production consist of 25 Bcf of natural gas, 3,799 MBbls of NGLs and 639 MBbls of oil. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
During the first nine months of 2017, Southwestern invested a total of approximately $921 million in the E&P business and participated in drilling 106 wells, completed 118 wells, and placed 130 wells to sales.
Nine Months Ended Sept 30, 2017 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) (1) |
285 |
131 |
241 | |||||
Gross operated production as of Sept 30, 2017 (MMcfe/d) |
1,408 |
958 |
1,232 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
315 |
$ |
244 |
$ |
73 | ||
Acquisition and leasehold |
12 |
46 |
1 | |||||
Seismic and other |
9 |
3 |
6 | |||||
Capitalized interest and expense |
31 |
97 |
17 | |||||
Total capital investments |
$ |
367 |
$ |
390 |
$ |
97 | ||
Gross operated well count summary |
||||||||
Drilled |
56 |
36 |
13 | |||||
Completed |
57 |
38 |
22 | |||||
Wells to sales |
60 |
46 |
23 | |||||
Realized Price |
||||||||
NYMEX Henry Hub Price ($/MMBtu) |
$ |
3.17 |
$ |
3.17 |
$ |
3.17 | ||
Discount to NYMEX ($/Mcf)(2) |
$ |
(0.95) |
$ |
(0.78) |
$ |
(0.78) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
2.22 |
$ |
2.39 |
$ |
2.39 |
(1) |
SW Appalachia production consisted of 60 Bcf of natural gas, 10,098 MBbls of NGLs and 1,673 MBbls of oil. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
Southwest Appalachia – The Company's net production from Southwest Appalachia was 52 Bcfe in the third quarter 2017, a 41% increase compared to the same quarter in 2016. Southwest Appalachia achieved record gross operated exit production rates of 958 MMcfe per day, a 54% increase compared to the third quarter of 2016. Southwestern brought online 18 wells in Southwest Appalachia in the third quarter, which included 17 Marcellus wells and one Utica well. The 17 Marcellus wells had an average lateral length of 6,958 feet and an average cost of $6.7 million per well. In Marshall County, Southwestern placed the four-well Gladys Briggs pad to sales in July with an average completed lateral length of 6,576 feet. The pad is currently producing at a rate of 58 MMcfe per day, comprised of 42% liquids, with an average flowing casing pressure of 2,250 psi. This productivity exceeds the Company's lean gas type curve and results in an estimated pad finding and development costs of less than $0.25 per Mcfe.
During the third quarter of 2017, two key commercial development opportunities that expand margins and create significant long-term value were finalized in Southwest Appalachia.
Southwestern continues to improve capital efficiency with drilling advancements, lowering costs and increasing recoveries. The Company set two drilling records in the third quarter. The first was on the John Hupp 3H in Brooke County, West Virginia, where 6,202 feet of lateral was drilled 100% in zone of a 15 foot target window, setting a new 24 hour drilling record. The second was on the William Rogers 405H well in Ohio County, West Virginia, which was drilled to a total depth of 13,927 feet in less than 10 days from rig release to rig release. These well results demonstrate how advanced technology is improving operational performance.
The Company's second Utica well, the Marlin Funka 9H was placed online in August 2017. The well had a lateral length of 4,572 feet and was flowing at a rate of 23 MMcf per day prior to being shut in to perform additional tests. The well is expected to flow between 16 and 20 MMcf per day as part of its pressure management program when it is brought back online in the fourth quarter. The Company is encouraged with the initial results and the repeated deliverability demonstrated by its first two wells of the estimated 1,400 locations in its portfolio.
Northeast Appalachia – The Company's net production from Northeast Appalachia was 101 Bcfe in the third quarter 2017, a 20% increase compared to the same quarter in 2016. Northeast Appalachia also achieved record gross operated exit production rates of 1,408 MMcfe per day, a 35% increase compared to the third quarter of 2016. In the third quarter of 2017, the Company placed 15 wells to sales, which had an average lateral length of 8,093 feet and an average cost of $7.2 million per well. The average rate for the first 30 days for the six wells that were online for at least 30 days was 15.7 MMcf per day.
The Company continued its delineation success utilizing enhanced completion designs in Tioga and western Susquehanna Counties, placing seven wells to sales with strong early results. For example, in Tioga County, the Company placed a four-well pad to sales with an average lateral length of approximately 7,500 feet and combined maximum rate of over 80 MMcf per day, flowing against 1,200 psi of line pressure. Additionally, the Company placed its first three-well pad to sales in the Susquehanna County acreage acquired in 2015 with an average lateral length of over 10,000 feet and combined maximum rate of over 62 MMcf per day. One of the wells on this pad utilized an advanced completion design and produced at 33 MMcf per day. The learnings from this well will be applied to future wells in this area.
The Company also generated an additional $0.09 per Mcf on its Northeast Appalachia volumes with its financial basis hedges in the third quarter as basis differentials widened as a result of increased production and delayed in-service dates on new takeaway projects. The current financial basis hedge position is expected to generate an additional $0.11 of benefit during the fourth quarter of 2017 based on current futures strip pricing, with the majority of protection being in October. The diversified firm transportation portfolio continues to position the Company to maximize realized pricing based on market dynamics, and the Company currently expects its 2018 price realizations in Northeast Appalachia to improve by over $0.25 per Mcf as additional infrastructure is placed into service.
Fayetteville Shale – During the third quarter of 2017, the Company placed three wells to sales, including two Moorefield delineation wells. The two Moorefield wells had an average lateral length of 7,495 feet and an average cost of $5.3 million per well. These two step-out wells incorporated learnings from previous well results, delivering an initial production rate of 5.4 MMcf per day and an average EUR of 5.5 Bcf. The Company plans to test two additional wells in the fourth quarter to further test the aerial extent of its Moorefield acreage.
Additionally, the Company successfully renegotiated its Fayetteville firm transportation agreement, subject to FERC approval, providing savings of approximately $70 million from 2017 through 2020, including $45 million in 2018. This agreement also secures flexible take-away capacity at reduced rates of approximately $0.10 per MMBtu after 2020, a reduction of over 60% compared to the current average rate of $0.26 per MMBtu. The Company is pursuing additional opportunities to further enhance margins and lower the break-even cost across the play.
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three and nine months ended September 30, 2017 and September 30, 2016, and as of September 30, 2017 and December 31, 2016, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net income (loss) attributable to common stock |
$ |
43 |
$ |
(735) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
2 |
(2) | |||
Impairment of natural gas and oil properties |
− |
817 | |||
Restructuring charges |
− |
2 | |||
(Gain) on certain derivatives |
(31) |
(81) | |||
Loss on early extinguishment of debt(1) |
59 |
57 | |||
Adjustments due to inventory valuation and other |
− |
(1) | |||
Legal settlements |
5 |
− | |||
Adjustments due to discrete tax items(1) |
(37) |
256 | |||
Tax impact on adjustments |
(12) |
(301) | |||
Adjusted net income attributable to common stock |
$ |
29 |
$ |
12 |
(1) |
2016 includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest changes. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
9 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net income (loss) attributable to common stock |
$ |
548 |
$ |
(2,514) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
59 |
− | |||
Impairment of natural gas and oil properties |
− |
2,321 | |||
Restructuring charges |
− |
77 | |||
(Gain) loss on certain derivatives |
(350) |
48 | |||
Gain on sale of assets, net |
(3) |
(2) | |||
Loss on early extinguishment of debt(1) |
70 |
57 | |||
Adjustments due to inventory valuation and other |
(1) |
3 | |||
Legal settlements |
5 |
− | |||
Adjustments due to discrete tax items(2) |
(279) |
903 | |||
Tax impact on adjustments |
107 |
(945) | |||
Adjusted net income (loss) attributable to common stock |
$ |
156 |
$ |
(52) |
(1) |
2016 includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest changes. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended September 30, | |||||
2017 |
2016 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted earnings (loss) per share |
$ |
0.09 |
$ |
(1.52) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
0.00 |
(0.00) | |||
Impairment of natural gas and oil properties |
− |
1.69 | |||
Restructuring charges |
− |
0.01 | |||
(Gain) on certain derivatives |
(0.06) |
(0.17) | |||
Loss on early extinguishment of debt(1) |
0.12 |
0.12 | |||
Adjustments due to inventory valuation and other |
− |
(0.00) | |||
Legal settlements |
0.01 |
− | |||
Adjustments due to discrete tax items(2) |
(0.07) |
0.53 | |||
Tax impact on adjustments |
(0.03) |
(0.63) | |||
Adjusted diluted earnings per share |
$ |
0.06 |
$ |
0.03 |
(1) |
2016 includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest changes. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
9 Months Ended September 30, | |||||
2017 |
2016 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted earnings (loss) per share |
$ |
1.10 |
$ |
(6.02) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
0.12 |
− | |||
Impairment of natural gas and oil properties |
− |
5.56 | |||
Restructuring charges |
− |
0.19 | |||
(Gain) loss on certain derivatives |
(0.70) |
0.12 | |||
Gain on sale of assets, net |
(0.01) |
(0.01) | |||
Loss on early extinguishment of debt |
0.14 |
0.14 | |||
Adjustments due to inventory valuation and other |
(0.00) |
0.01 | |||
Legal settlements |
0.01 |
− | |||
Adjustments due to discrete tax items(1) |
(0.56) |
2.16 | |||
Tax impact on adjustments |
0.21 |
(2.27) | |||
Adjusted diluted earnings (loss) per share |
$ |
0.31 |
$ |
(0.12) |
(1) |
2016 includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest changes. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
211 |
$ |
172 | |
Add back: |
|||||
Changes in operating assets and liabilities |
37 |
− | |||
Restructuring charges |
− |
1 | |||
Net Cash Flow |
$ |
248 |
$ |
173 | |
9 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
789 |
$ |
337 | |
Add back: |
|||||
Changes in operating assets and liabilities |
27 |
50 | |||
Restructuring charges |
− |
47 | |||
Net Cash Flow |
$ |
816 |
$ |
434 | |
3 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating income (loss) |
$ |
110 |
$ |
(725) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
817 | |||
Restructuring charges and other charges |
– |
2 | |||
Legal settlements |
5 |
– | |||
Gain on sale of assets, net |
(3) |
– | |||
Adjusted operating income |
$ |
112 |
$ |
94 | |
9 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating income (loss) |
$ |
564 |
$ |
(2,317) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
2,321 | |||
Restructuring charges and other charges |
– |
77 | |||
Legal settlements |
5 |
– | |||
Gain on sale of assets, net |
(3) |
– | |||
Adjusted operating income |
$ |
566 |
$ |
81 | |
3 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
64 |
$ |
(777) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
817 | |||
Restructuring charges and other charges |
– |
2 | |||
Legal settlements |
5 |
– | |||
Adjusted E&P segment operating income |
$ |
69 |
$ |
42 | |
9 Months Ended September 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
435 |
$ |
(2,486) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
2,321 | |||
Restructuring charges and other charges |
– |
74 | |||
Legal settlements |
5 |
– | |||
Adjusted E&P segment operating income (loss) |
$ |
440 |
$ |
(91) | |
September 30, |
December 31, | ||||
2017 |
2016 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
4,436 |
$ |
4,653 | |
Subtract: |
|||||
Cash and cash equivalents |
(989) |
(1,423) | |||
Net debt |
$ |
3,447 |
$ |
3,230 |
Southwestern management will host a teleconference call on Friday, October 27, 2017 at 10:00 a.m. Eastern to discuss its third quarter 2017 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
Cautionary Note to U.S. Investors – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves. We use the term "EUR" in this release that the SEC's guidelines prohibit us from including in filings with the SEC. The quarterly reserves data included in this release are estimates we prepared that have not been audited by our independent reserve engineers. U.S. investors are urged to consider closely the oil and gas disclosures in our Form 10-K and other reports and filings with the SEC. Copies are available from the SEC and from the Southwestern Energy Company website.
OPERATING STATISTICS (Unaudited) | |||||||||||
Southwestern Energy Company and Subsidiaries | |||||||||||
For the three months ended |
For the nine months ended | ||||||||||
September 30, |
September 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Exploration & Production |
|||||||||||
Production |
|||||||||||
Gas production (Bcf) |
205 |
189 |
587 |
605 | |||||||
Oil production (MBbls) |
663 |
536 |
1,747 |
1,729 | |||||||
NGL production (MBbls) |
3,810 |
3,068 |
10,134 |
9,580 | |||||||
Total production (Bcfe) |
232 |
211 |
658 |
673 | |||||||
Commodity Prices |
|||||||||||
Average realized gas price per Mcf, including derivatives |
$ |
1.97 |
$ |
1.73 |
$ |
2.22 |
$ |
1.51 | |||
Average realized gas price per Mcf, excluding derivatives |
$ |
1.89 |
$ |
1.78 |
$ |
2.31 |
$ |
1.47 | |||
Average realized oil price per Bbl |
$ |
40.49 |
$ |
35.41 |
$ |
41.48 |
$ |
28.53 | |||
Average realized NGL price per Bbl |
$ |
14.47 |
$ |
7.04 |
$ |
13.06 |
$ |
6.11 | |||
Summary of Derivative Activity in the Statement of Operations |
|||||||||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) (1) |
$ |
17 |
$ |
(9) |
$ |
(52) |
$ |
22 | |||
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
30 |
$ |
81 |
$ |
349 |
$ |
(45) | |||
Average unit costs per Mcfe |
|||||||||||
Lease operating expenses |
$ |
0.91 |
$ |
0.86 |
$ |
0.90 |
$ |
0.87 | |||
General & administrative expenses (2) |
$ |
0.23 |
$ |
0.23 |
$ |
0.22 |
$ |
0.21 | |||
Taxes, other than income taxes (3) |
$ |
0.10 |
$ |
0.10 |
$ |
0.10 |
$ |
0.09 | |||
Full cost pool amortization |
$ |
0.48 |
$ |
0.35 |
$ |
0.44 |
$ |
0.40 | |||
Midstream |
|||||||||||
Volumes marketed (Bcfe) |
273 |
264 |
782 |
814 | |||||||
Volumes gathered (Bcf) |
123 |
145 |
380 |
463 |
(1) |
Excludes $3 million amortization of premiums paid related to certain call options for the three and nine months ended September 30, 2017, which is included in gain (loss) on derivatives on the statements of operations (unaudited). |
(2) |
Excludes $2 million and $71 million of restructuring charges for the three and nine months ended September 30, 2016, respectively. |
(3) |
Excludes $3 million of restructuring charges for the nine months ended September 30, 2016. |
STATEMENTS OF OPERATIONS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the nine months ended | |||||||||||
September 30, |
September 30, | |||||||||||
2017 |
2016 |
2017 |
2016 | |||||||||
(in millions, except share/per share amounts) | ||||||||||||
Operating Revenues |
||||||||||||
Gas sales |
$ |
394 |
$ |
340 |
$ |
1,368 |
$ |
906 | ||||
Oil sales |
27 |
19 |
73 |
50 | ||||||||
NGL sales |
55 |
22 |
132 |
59 | ||||||||
Marketing |
233 |
237 |
736 |
631 | ||||||||
Gas gathering |
28 |
33 |
85 |
106 | ||||||||
737 |
651 |
2,394 |
1,752 | |||||||||
Operating Costs and Expenses |
||||||||||||
Marketing purchases |
236 |
234 |
740 |
627 | ||||||||
Operating expenses |
170 |
139 |
481 |
455 | ||||||||
General and administrative expenses |
62 |
61 |
170 |
171 | ||||||||
Restructuring charges |
– |
2 |
– |
77 | ||||||||
Depreciation, depletion and amortization |
135 |
99 |
364 |
349 | ||||||||
Impairment of natural gas and oil properties |
– |
817 |
– |
2,321 | ||||||||
Taxes, other than income taxes |
24 |
24 |
75 |
69 | ||||||||
627 |
1,376 |
1,830 |
4,069 | |||||||||
Operating Income (Loss) |
110 |
(725) |
564 |
(2,317) | ||||||||
Interest Expense |
||||||||||||
Interest on debt |
58 |
59 |
175 |
168 | ||||||||
Other interest charges |
2 |
8 |
7 |
12 | ||||||||
Interest capitalized |
(29) |
(41) |
(85) |
(123) | ||||||||
31 |
26 |
97 |
57 | |||||||||
Gain (Loss) on Derivatives |
45 |
71 |
295 |
(28) | ||||||||
Loss on Early Extinguishment of Debt |
(59) |
(51) |
(70) |
(51) | ||||||||
Other Income (Loss), Net |
(2) |
3 |
6 |
– | ||||||||
Income (Loss) Before Income Taxes |
63 |
(728) |
698 |
(2,453) | ||||||||
Benefit for Income Taxes |
||||||||||||
Current |
(10) |
– |
(10) |
– | ||||||||
Deferred |
(4) |
(20) |
(4) |
(20) | ||||||||
(14) |
(20) |
(14) |
(20) | |||||||||
Net Income (Loss) |
77 |
(708) |
712 |
(2,433) | ||||||||
Mandatory convertible preferred stock dividend |
27 |
27 |
81 |
81 | ||||||||
Participating securities - mandatory convertible preferred stock |
7 |
– |
83 |
– | ||||||||
Net Income (Loss) Attributable to Common Stock |
$ |
43 |
$ |
(735) |
$ |
548 |
$ |
(2,514) | ||||
Earnings (Loss) Per Common Share |
||||||||||||
Basic |
$ |
0.09 |
$ |
(1.52) |
$ |
1.11 |
$ |
(6.02) | ||||
Diluted |
$ |
0.09 |
$ |
(1.52) |
$ |
1.10 |
$ |
(6.02) | ||||
Weighted Average Common Shares Outstanding |
||||||||||||
Basic |
499,812,926 |
482,485,150 |
496,458,435 |
417,222,661 | ||||||||
Diluted |
502,290,779 |
482,485,150 |
498,527,671 |
417,222,661 |
BALANCE SHEETS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
September 30, |
December 31, | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,476 |
$ |
1,872 | ||
Property and equipment |
25,454 |
24,489 | ||||
Less: Accumulated depreciation, depletion and amortization |
(19,904) |
(19,534) | ||||
Total property and equipment, net |
5,550 |
4,955 | ||||
Other long-term assets |
176 |
249 | ||||
Total assets |
7,202 |
7,076 | ||||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
784 |
1,064 | ||||
Long-term debt |
4,396 |
4,612 | ||||
Pension and other postretirement liabilities |
46 |
49 | ||||
Other long-term liabilities |
324 |
434 | ||||
Total liabilities |
5,550 |
6,159 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 509,142,659 shares as of September 30, 2017 (does not include 3,346,703 shares issued on October 16, 2017 on account of a dividend declared on September 15, 2017) and 495,248,369 as of December 31, 2016 |
5 |
5 | ||||
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of September 30, 2017 and December 31, 2016, conversion in January 2018 |
– |
– | ||||
Additional paid-in capital |
4,698 |
4,677 | ||||
Accumulated deficit |
(3,013) |
(3,725) | ||||
Accumulated other comprehensive loss |
(37) |
(39) | ||||
Common stock in treasury; 31,269 shares as of September 30, 2017 and December 31, 2016 |
(1) |
(1) | ||||
Total equity |
1,652 |
917 | ||||
Total liabilities and equity |
$ |
7,202 |
$ |
7,076 |
STATEMENTS OF CASH FLOWS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
For the nine months ended | ||||||
September 30, | ||||||
2017 |
2016 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities |
||||||
Net income (loss) |
$ |
712 |
$ |
(2,433) | ||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
||||||
Depreciation, depletion and amortization |
364 |
349 | ||||
Impairment of natural gas and oil properties |
– |
2,321 | ||||
Amortization of debt issuance costs |
7 |
12 | ||||
Deferred income taxes |
(4) |
(20) | ||||
(Gain) loss on derivatives, unsettled |
(350) |
48 | ||||
Stock-based compensation |
19 |
24 | ||||
Restructuring charges |
– |
30 | ||||
Loss on early extinguishment of debt |
70 |
51 | ||||
Other |
(2) |
5 | ||||
Change in assets and liabilities |
(27) |
(50) | ||||
Net cash provided by operating activities |
789 |
337 | ||||
Cash Flows From Investing Activities |
||||||
Capital investments |
(943) |
(391) | ||||
Proceeds from sale of property and equipment |
17 |
434 | ||||
Other |
5 |
– | ||||
Net cash provided by (used in) investing activities |
(921) |
43 | ||||
Cash Flows From Financing Activities |
||||||
Payments on short-term debt |
(287) |
(1) | ||||
Payments on long-term debt |
(1,139) |
(1,175) | ||||
Payments on revolving credit facility |
– |
(3,268) | ||||
Borrowings under revolving credit facility |
– |
3,152 | ||||
Payments on commercial paper |
– |
(242) | ||||
Borrowings under commercial paper |
– |
242 | ||||
Change in bank drafts outstanding |
– |
(19) | ||||
Proceeds from issuance of long-term debt |
1,150 |
1,191 | ||||
Debt issuance costs |
(18) |
(17) | ||||
Proceeds from issuance of common stock |
– |
1,247 | ||||
Preferred stock dividend |
(8) |
(27) | ||||
Other |
– |
(4) | ||||
Net cash provided by (used in) financing activities |
(302) |
1,079 | ||||
Increase (decrease) in cash and cash equivalents |
(434) |
1,459 | ||||
Cash and cash equivalents at beginning of year |
1,423 |
15 | ||||
Cash and cash equivalents at end of period |
$ |
989 |
$ |
1,474 |
SEGMENT INFORMATION (Unaudited) |
|||||||||||||||
Southwestern Energy Company and Subsidiaries |
|||||||||||||||
Exploration and Production |
Midstream Services |
Other |
Eliminations |
Total | |||||||||||
(in millions) | |||||||||||||||
Three months ended September 30, 2017 |
|||||||||||||||
Revenues |
$ |
470 |
$ |
734 |
$ |
– |
$ |
(467) |
$ |
737 | |||||
Marketing purchases |
– |
645 |
– |
(409) |
236 | ||||||||||
Operating expenses |
210 |
18 |
– |
(58) |
170 | ||||||||||
General and administrative expenses |
54 |
8 |
– |
– |
62 | ||||||||||
Depreciation, depletion and amortization |
120 |
15 |
– |
– |
135 | ||||||||||
Taxes, other than income taxes |
22 |
2 |
– |
– |
24 | ||||||||||
Operating income |
64 |
46 |
– |
– |
110 | ||||||||||
Capital investments (1) |
320 |
9 |
2 |
– |
331 | ||||||||||
Three months ended September 30, 2016 |
|||||||||||||||
Revenues |
$ |
378 |
$ |
682 |
$ |
– |
$ |
(409) |
$ |
651 | |||||
Marketing purchases |
– |
578 |
– |
(344) |
234 | ||||||||||
Operating expenses |
181 |
23 |
– |
(65) |
139 | ||||||||||
General and administrative expenses |
50 |
11 |
– |
– |
61 | ||||||||||
Restructuring charges |
2 |
– |
– |
– |
2 | ||||||||||
Depreciation, depletion and amortization |
83 |
16 |
– |
– |
99 | ||||||||||
Impairment of natural gas and oil properties |
817 |
– |
– |
– |
817 | ||||||||||
Taxes, other than income taxes |
22 |
2 |
– |
– |
24 | ||||||||||
Operating income (loss) |
(777) |
52 |
– |
– |
(725) | ||||||||||
Capital investments (1) |
179 |
1 |
– |
– |
180 | ||||||||||
Nine months ended September 30, 2017 |
|||||||||||||||
Revenues |
$ |
1,559 |
$ |
2,414 |
$ |
– |
$ |
(1,579) |
$ |
2,394 | |||||
Marketing purchases |
– |
2,141 |
– |
(1,401) |
740 | ||||||||||
Operating expenses |
591 |
68 |
– |
(178) |
481 | ||||||||||
General and administrative expenses |
147 |
23 |
– |
– |
170 | ||||||||||
Depreciation, depletion and amortization |
317 |
47 |
– |
– |
364 | ||||||||||
Taxes, other than income taxes |
69 |
6 |
– |
– |
75 | ||||||||||
Operating income |
435 |
129 |
– |
– |
564 | ||||||||||
Capital investments (1) |
921 |
21 |
4 |
– |
946 | ||||||||||
Nine months ended September 30, 2016 |
|||||||||||||||
Revenues |
$ |
998 |
$ |
1,862 |
$ |
– |
$ |
(1,108) |
$ |
1,752 | |||||
Marketing purchases |
– |
1,533 |
– |
(906) |
627 | ||||||||||
Operating expenses |
586 |
71 |
– |
(202) |
455 | ||||||||||
General and administrative expenses |
141 |
30 |
– |
– |
171 | ||||||||||
Restructuring charges |
74 |
3 |
– |
– |
77 | ||||||||||
Depreciation, depletion and amortization |
300 |
49 |
– |
– |
349 | ||||||||||
Impairment of natural gas and oil properties |
2,321 |
– |
– |
– |
2,321 | ||||||||||
Taxes, other than income taxes |
62 |
7 |
– |
– |
69 | ||||||||||
Operating income (loss) |
(2,486) |
169 |
– |
– |
(2,317) | ||||||||||
Capital investments (1) |
372 |
3 |
1 |
– |
376 |
(1) |
Capital investments includes a decrease of $2 million and an increase of $27 million for the three months ended September 30, 2017 and 2016, respectively, and decreases of $13 million and $24 million for the nine months ended September 30, 2017 and 2016, respectively, relating to the change in capital accruals between periods. |
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-third-quarter-2017-financial-and-operating-results-300544484.html
SOURCE Southwestern Energy Company
HOUSTON, Oct. 16, 2017 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2017 Third Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, October 27, 2017, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Third Quarter 2017 Earnings |
When: |
October 27, 2017 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live Webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
View original content:http://www.prnewswire.com/news-releases/webcast-alert--southwestern-energy-company-invites-you-to-join-its-third-quarter-2017-earnings-conference-call-on-the-web-300527918.html
SOURCE Southwestern Energy Company
HOUSTON, Oct. 10, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced final results and expiration of the previously announced cash tender offers (the "Tender Offers") to purchase (i) any and all of the Company's 4.05% senior notes due 2020 (the "2020 Notes") and (ii) up to an amount of the Company's 4.10% senior notes due 2022 (the "2022 Notes") and 4.95% senior notes due 2025 (the "2025 Notes") equal to $800 million (subject to increase by the Company, the "Threshold Amount") less the aggregate purchase price paid for the 2020 Notes accepted for purchase, excluding accrued interest (as it may be increased by the Company, the "Maximum Aggregate Purchase Price"). Because the Maximum Aggregate Purchase Price exceeds the Threshold Amount, no 2022 Notes or 2025 Notes will be accepted for purchase in the Tender Offers.
The Company previously accepted for purchase the $757.6 million aggregate principal amount of its 2020 Notes that were validly tendered as of 5:00 p.m., New York City time, on September 25, 2017 (that date and time, the "Early Settlement Date"). According to information received from D.F. King & Co., Inc. ("D.F. King"), the Tender Agent and Information Agent for the Tender Offers, in accordance with the terms of the Tender Offers, an additional $0.8 million aggregate principal amount of the 2020 Notes (the "Final Tender Amount") were validly tendered after the Early Settlement Date but at or prior to 12:00 midnight, New York City time, on October 6, 2017 (that date and time, the "Expiration Date"). On the "Final Settlement Date," which is currently expected to occur on the date hereof, the Company intends to purchase all of the Final Tender Amount.
J.P. Morgan Securities LLC ("J.P. Morgan") is the Lead Dealer Manager in the Tender Offers and Consent Solicitation. D.F. King has been retained to serve as the Tender Agent and Information Agent for the Tender Offers and Consent Solicitation. Persons with questions regarding the Tender Offers and Consent Solicitation should contact J.P. Morgan at (toll free) (866) 834-4666 or (collect) (212) 834-8553. Requests for the Offer to Purchase should be directed to D.F. King at (toll free) (866) 406-2283 or by email to swn@dfking.com.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Tender Offers were made only pursuant to the Offer to Purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers will be deemed to be made on behalf of the Company by the Dealer Managers, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-final-results-and-expiration-of-cash-tender-offers-300533542.html
SOURCE Southwestern Energy Company
HOUSTON, Oct. 2, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that it has signed an amended transportation agreement with Boardwalk Pipeline Partners' (NYSE:BWP) Texas Gas Transmission, LLC subsidiary for a portion of its Fayetteville firm takeaway capacity, subject to approval from the Federal Energy Regulatory Commission. This new agreement is effective November 1, 2017 and is expected to provide savings of approximately $70 million from 2017 through 2020, including approximately $45 million in savings in 2018 through the reduction of current excess capacity, while guaranteeing future flexible takeaway capacity through 2030 at competitive rates. Key components of this amended agreement include:
"We are very excited about this new agreement and the opportunity to continue our long-standing relationship with an exceptional company like Texas Gas," commented Bill Way, President and Chief Executive Officer of Southwestern Energy. "This agreement further enhances our margins and reduces excess demand capacity while securing option capacity for future development. It also provides the flexibility to ramp activity in the Fayetteville and Moorefield area as economics dictate at competitive transportation rates without incurring additional liabilities during times of decreased activity."
Total Fayetteville Firm Transportation Terms: |
Previous Firm Transportation Terms |
Renegotiated Firm Transportation Terms | ||||||||||||||
Committed |
Reservation |
Annual |
Committed |
Reservation |
Annual | ||||||||||
Volumes |
Rate(1) |
Obligation |
Volumes |
Rate(1) |
Obligation | ||||||||||
(Bcf/d) |
($/MMBtu) |
($MMs) |
(Bcf/d) |
($/MMBtu) |
($MMs) | ||||||||||
2017 |
2.00 |
$0.26 |
$191.5 |
1.88 |
$0.27 |
$184.1 | |||||||||
2018 |
2.00 |
$0.26 |
$191.5 |
1.30 |
$0.31 |
$147.5 | |||||||||
2019 |
1.62 |
$0.25 |
$150.9 |
1.30 |
$0.29 |
$135.5 | |||||||||
2020 |
1.45 |
$0.24 |
$125.8 |
1.28 |
$0.26 |
$121.7 | |||||||||
2021-2030 |
- |
- |
- |
See below |
$0.10 |
$12.8(2) |
(1) Total reservation rate includes 1.2 Bcf per day capacity on Fayetteville Express through December 2020 and impact of 0.64 Bcf per day capacity on Texas Gas Transmission's Greenville Lateral pipeline, which is additive to the rates on Texas Gas Transmission's Fayetteville lateral |
Capacity(1) (Bcf/d) |
2021 |
2022 |
2023 |
2024 |
2025 |
2026 |
2027 |
2028 |
2029 |
2030 |
Contracted firm |
0.55 |
0.50 |
0.45 |
0.40 |
0.35 |
0.30 |
0.30 |
0.25 |
0.23 |
0.20 |
Additional firm with volumetric optionality |
0.25 |
0.30 |
0.35 |
0.40 |
0.45 |
0.50 |
0.50 |
0.55 |
0.57 |
0.60 |
(1) All future incremental production above the contracted firm is committed to Texas Gas Transmission starting in 2021, under a tiered volumetric rate design of $0.05 and $0.08 per MMBtu up to 0.80 Bcf per day, at which point the volumetric commodity rate is fixed at $0.05 per MMBtu for any available capacity above the 0.80 Bcf per day. |
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
Cautionary Note to U.S. Investors – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves. We use the term "EUR" in this release that the SEC's guidelines prohibit us from including in filings with the SEC. The quarterly reserves data included in this release are estimates we prepared that have not been audited by our independent reserve engineers. U.S. investors are urged to consider closely the oil and gas disclosures in our Form 10-K and other reports and filings with the SEC. Copies are available from the SEC and from the Southwestern Energy Company website.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-successfully-renegotiates-fayetteville-firm-transportation-agreement-300528524.html
SOURCE Southwestern Energy Company
HOUSTON, Oct. 2, 2017 /PRNewswire/ -- Boardwalk Pipeline Partners, LP (NYSE: BWP) announced today that its Texas Gas Transmission Company, LLC subsidiary (Texas Gas) has filed with the Federal Energy Regulatory Commission (FERC) seeking approval to restructure some of its existing firm transportation agreements and enter into new firm transportation agreements with subsidiaries of Southwestern Energy (NYSE: SWN) on Texas Gas' Fayetteville and Greenville Laterals.
"These agreements are value enhancing for Boardwalk. The restructuring of Southwestern's transportation agreements helps Texas Gas achieve greater long-term revenue generation. It also provides future revenue upside through Southwestern's volume commitment of flowing gas from the Fayetteville and Moorefield plays. Our relationship with Southwestern and their long-term commitment to Texas Gas will provide an important source of supplies to support the growth of our end-use markets," stated Stan Horton, Boardwalk's president and CEO.
The agreement lowers the contract quantities for Southwestern's existing firm transportation contracts on the Fayetteville Lateral through 2020 and adds new long-term firm transportation agreements on the Fayetteville and Greenville Laterals through 2030. Boardwalk will also have rights through 2030 to transport natural gas produced from the committed volumes that Southwestern Energy produces in the Fayetteville and Moorefield plays.
For more information about the underlying firm transportation agreements, please refer to the Texas Gas FERC filing submitted on September 29, 2017, which can be accessed through this link: Texas Gas FERC Filing of Southwestern Restructuring. The terms of the other existing firm transportation agreements between Texas Gas and Southwestern will remain unchanged.
The chart compares the demand charge anticipated revenues under the existing contracts and the proposed new contracts.
About Boardwalk: Boardwalk Pipeline Partners, LP (NYSE: BWP) is a midstream master limited partnership that transports and stores natural gas and liquids for its customers. Additional information about the Partnership can be found on its website at www.bwpmlp.com.
Forward-Looking Statement: This press release contains forward-looking statements relating to expectations, plans or prospects for Boardwalk Pipeline Partners, LP and its subsidiaries, relating to, among other things, approval of the restructured contracts by FERC and the resulting anticipated revenues from the restructured contracts. These statements are based upon the beliefs and expectations of Boardwalk management based on currently available information and expectations, and management expressly disclaims any obligation to update or revise these statements to reflect any change in its expectations, plans or prospects or any change in events, conditions or circumstances. Actual results may differ materially from those projected in this press release, due to a wide range of risks and uncertainties, including those set forth in our SEC documents.
CONTACT:
Molly Ladd Whitaker, 866-913-2122
Director of Investor Relations and Corporate Communications
ir@bwpmlp.com
View original content with multimedia:http://www.prnewswire.com/news-releases/boardwalk-restructures-and-extends-firm-transportation-service-agreements-with-southwestern-energy-300528607.html
SOURCE Boardwalk Pipeline Partners, LP
HOUSTON, Sept. 25, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced the completion of its previously announced public offering (the "Offering") of $1.15 billion aggregate principal amount of senior notes, consisting of $650 million aggregate principal amount of 7.500% senior notes due 2026 (the "2026 Notes") and $500 million aggregate principal amount of its 7.750% senior notes due 2027 (the "2027 Notes" and, together with the 2026 Notes, the "Notes"), with net proceeds from the Offering totaling approximately $1,133 million after underwriting discounts and offering expenses.
The Notes were sold to the public at a price of 100.000% of their face value for the 2026 Notes and 100.000% of their face value for the 2027 Notes.
The proceeds from the Offering were used to repay in full and terminate the Company's Amended and Restated Term Loan Credit Agreement with various lenders and Bank of America, N.A., as administrative agent and lender, and the remaining net proceeds from the Offering, together with cash on hand, will be used to fund the Company's previously announced tender offers and consent solicitation.
J.P. Morgan Securites LLC; Citigroup Global Markets Inc.; MUFG Securities Americas Inc.; BofA Merrill Lynch; Credit Agricole Securities (USA) Inc.; Mizuho Securities USA LLC; RBC Capital Markets, LLC and Wells Fargo Securities, LLC acted as joint book-running managers for the Offering. The Offering was made under an automatic shelf registration statement on Form S-3 (Registration No. 333-208074) filed by the Company with the Securities and Exchange Commission ("SEC") and only by means of a prospectus supplement and accompanying prospectus. Prospective investors should read the prospectus supplement and the accompanying prospectus included in the registration statement and other documents the Company has filed with the SEC for more complete information about the Company and the Offering. Copies of the prospectus supplement and the accompanying prospectus related to the Offering are available at no charge by visiting EDGAR on the SEC Web site at http://www.sec.gov. Alternatively, any underwriter or any dealer participating in the Offering will arrange to send you the prospectus and related prospectus supplement if you request it by contacting:
J.P. Morgan Securities LLC
c/o Broadridge Financial Solutions
1155 Long Island Avenue
Edgewood, NY 11711
1-866-803-9204
This news release shall not constitute an offer to sell or the solicitation of an offer to buy the securities described above, nor shall there be any sale of, or any solicitation of an offer to buy, these securities in any state or jurisdiction in which such offer, solicitation or sale of these securities would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
This news release includes forward-looking statements as defined under federal law, including those related to the Company's offering and the use of proceeds. There can be no assurance that such expectation or belief will result or be achieved. The Company's future actions and results can and will be affected by a variety of risks and other matters including, but not limited to, changes in commodity prices; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws applicable to the Company's 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 the Company's business generally as set forth in its filings with the SEC. Unless legally required, the Company undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-closing-of-public-offering-of-115-billion-of-senior-notes-300525322.html
SOURCE Southwestern Energy Company
HOUSTON, Sept. 25, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced early results of the previously announced cash tender offers (the "Tender Offers") to purchase (i) any and all of the Company's 4.05% senior notes due 2020 (the "2020 Notes") and (ii) an amount of the Company's 4.10% senior notes due 2022 (the "2022 Notes) and 4.95% senior notes due 2025 (the "2025 Notes" and, together with the 2022 Notes, the "Maximum Tender Offer Notes," and collectively with the 2020 Notes and 2022 Notes, the "Notes") up to an amount equal to $800 million (subject to increase by the Company, the "Threshold Amount") less the aggregate purchase price paid for the 2020 Notes accepted for purchase, excluding accrued interest (as it may be increased by the Company, the "Maximum Aggregate Purchase Price").
According to information received from D.F. King & Co., Inc. ("D.F. King"), the Tender Agent and Information Agent for the Tender Offers, as of 5:00 p.m., New York City time, on September 22, 2017 (that date and time, the "Early Tender Time"), the Company had received valid tenders from holders of the Notes as outlined in the table below.
Aggregate (U.S. $) |
Principal Amount Tendered (U.S. $) |
Principal Amount Accepted(U.S. $) |
Acceptance Priority Level |
Total Consideration per U.S. $1,000 Principal Amount of Notes(1)(2) (U.S. $) | ||
Title of Notes |
CUSIP Number | |||||
Any and All Tender Offer Notes: |
||||||
4.05% Senior Notes due 2020(3) |
845467AK5 |
$850,000,000 |
$757,617,000 |
$757,617,000 |
N/A |
$1,070.00 |
Maximum Tender Offer Notes: |
||||||
4.10% Senior Notes due 2022 |
845467AF6; 845467AH2; U84517AB4 |
$1,000,000,000 |
$263,339,000 |
None |
1 |
$960.00 |
4.95% Senior Notes due 2025(3) |
845467AL3 |
$1,000,000,000 |
$161,837,000 |
None |
2 |
$1,005.00 |
________________ | |
(1) |
Does not include Accrued Interest, which will also be payable to but not including the applicable settlement date. |
(2) |
Includes the Early Tender Premium. |
(3) |
In February and June 2016, Moody's and S&P downgraded certain senior notes of the Company, increasing the interest rates by 175 basis points effective July 2016. As a result of downgrades, the interest rate increased to 5.80% for the 2020 Notes and to 6.70% for the 2025 Notes. |
Subject to the satisfaction or waiver of all remaining conditions to the Tender Offers described in the Company's Offer to Purchase, dated September 11, 2017 (the "Offer to Purchase"), having been either satisfied or waived by the Company, the Company intends to accept for purchase any and all of the 2020 Notes, subject to certain limits, validly tendered (and not validly withdrawn) before the Early Tender Time. The 2020 Notes will be purchased on the "Early Settlement Date," which is currently expected to occur on the date hereof.
Because the aggregate purchase price of the 2020 Notes expected to be purchased on the Early Settlement Date exceeds the Threshold Amount, no 2022 Notes or 2025 Notes will be accepted for purchase in the Tender Offers. Any 2022 Notes or 2025 Notes tendered prior to the Early Tender Time, together with all of the 2022 Notes and 2025 Notes tendered after the Early Tender Time, will be returned to the holders as described in the Offer to Purchase.
Concurrent with the Tender Offers, the Company also solicited consent from the holders of the 2020 Notes for proposed amendments (the "Proposed Amendments") to the terms of the 2020 Notes that would, among other things, amend certain restrictive covenants contained in the indenture governing the 2020 Notes. As of the Early Tender Time, holders of $757,617,000 aggregate principal amount of the 2020 Notes, representing 89% of the outstanding 2020 Notes, had validly tendered their 2020 Notes and were deemed to have delivered their consents to the Proposed Amendments by virtue of such tender. As a result, the number of consents required to approve the Proposed Amendments was received and the Proposed Amendments are expected to become effective on the date hereof.
Holders of 2020 Notes that were validly tendered (and not validly withdrawn) prior to the Early Tender Time and accepted for purchase pursuant to the Tender Offers will receive the applicable Total Consideration (as set forth in the table above) for such series, which includes the early tender premium of $50.00 for each series of Notes as set forth in the Offer to Purchase, together with accrued and unpaid interest from and including the last interest payment date for the 2020 Notes up to, but not including, the Early Settlement Date).
The financing condition described in the Offer to Purchase, and to which the Tender Offers is subject, is expected to be satisfied on the date hereof.
The Tender Offers will each expire at 12:00 midnight, New York City time, at the end of the day on October 6, 2017 (such date and time, as it may be extended, the "Expiration Date"). Holders of 2020 Notes validly tendered after the Early Tender Time and on or before the Expiration Date and accepted for purchase pursuant to the Tender Offers will receive the applicable Tender Offer Consideration, but no Early Tender Premium, as described in the Offer to Purchase, plus Accrued Interest (as defined in the Offer to Purchase). The Tender Offers are subject to the remaining conditions described in the Offer to Purchase. Full details of the terms and conditions of the Tender Offers are set forth in the Offer to Purchase, which is available from D.F. King.
J.P. Morgan Securities LLC ("J.P. Morgan") is the Lead Dealer Manager in the Tender Offers and Consent Solicitation. D.F. King has been retained to serve as the Tender Agent and Information Agent for the Tender Offers and Consent Solicitation. Persons with questions regarding the Tender Offers and Consent Solicitation should contact J.P. Morgan at (toll free) (866) 834-4666 or (collect) (212) 834-8553. Requests for the Offer to Purchase should be directed to D.F. King at (toll free) (866) 406-2283 or by email to swn@dfking.com.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Tender Offers are being made only pursuant to the Offer to Purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers will be deemed to be made on behalf of the Company by the Dealer Managers, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-early-results-of-tender-offers-300524938.html
SOURCE Southwestern Energy Company
HOUSTON, Sept. 15, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that an authorized committee of its Board of Directors declared a quarterly dividend of $15.625 per share on its 6.25% Series B Mandatory Convertible Preferred Stock, payable on October 16, 2017, to holders of record on October 1, 2017. This equates to $0.78125 for each depositary share, which represents a 1/20th interest in a share of the Series B preferred stock. The dividend is for the period beginning on July 15, 2017 and ending on October 14, 2017.
The company has elected to pay this dividend in shares of common stock of the company to the extent permitted by the certificate of designations governing the Series B preferred stock. Common shares issued will be listed and tradable on the New York Stock Exchange. If the value of the common stock, based on 97% of the volume weighted average trading price for the five consecutive trading day period ending the second trading day before the dividend payment date, would be below an amount specified in the certificate of designations, holders will receive the remainder of the dividend in cash.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Contact:
Michael Hancock
Vice President, Investor Relations
(832) 796-7367
michael_hancock@swn.com
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-declares-dividend-on-mandatory-convertible-preferred-stock-300520512.html
SOURCE Southwestern Energy Company
HOUSTON, Sept. 11, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced the pricing of its public offering (the "Offering") of $1.15 billion aggregate principal amount of senior notes, consisting of a $650 million series of 7.500% senior, unsecured notes due 2026 (the "2026 Notes") and a $500 million series of 7.750% senior, unsecured notes due 2027 (the "2027 Notes" and, together with the 2026 Notes, the "Notes"). The Notes will be sold to the public at a price of 100.000% of their face value for the 2026 Notes and 100.000% of their face value for the 2027 Notes. The expected settlement date for the Offering is September 25, 2017, subject to the satisfaction of customary closing conditions.
The Company expects to receive net proceeds from the Offering of approximately $1,133,000,000 after deducting the underwriting discounts and estimated offering expenses. The Company intends to use approximately $327 million of the net proceeds from the Offering to repay in full and terminate its 2015 Amended and Restated Term Loan with various lenders and Bank of America, N.A., as administrative agent and lender, and the remaining net proceeds of this Offering, together with cash on hand, to fund the previously announced tender offers to purchase for cash, subject to certain conditions, (i) any and all of the Company's 4.05% Senior Notes due 2020 (the "2020 Notes") and (ii) subject to certain limits, up to $100 million of each of the Company's 4.10% Senior Notes due 2022 and 4.95% Senior Notes due 2025 subject to the applicable priority levels and caps (collectively, the "Tender Offers"). If the Tender Offers are not consummated, or the aggregate amount of securities tendered in the Tender Offers and accepted for payment is less than the net proceeds of the Offering dedicated for that purpose, the Company will use the remainder of the net proceeds for other repayments of indebtedness, subject to the terms of the Company's credit facilities.
J.P. Morgan Securites LLC; Citigroup Global Markets Inc.; MUFG Securities Americas Inc.; BofA Merrill Lynch; Credit Agricole Securities (USA) Inc.; Mizuho Securities USA LLC; RBC Capital Markets, LLC and Wells Fargo Securities, LLC are acting as joint book-running managers for the Offering. The Offering is being made under an automatic shelf registration statement on Form S-3 (Registration No. 333-208074) filed by the Company with the Securities and Exchange Commission ("SEC") and only by means of a prospectus supplement and accompanying prospectus. A prospectus supplement will be filed with the SEC to which this communication relates. Prospective investors should read the prospectus supplement and the accompanying prospectus included in the registration statement and other documents the Company has filed with the SEC for more complete information about the Company and the Offering. These documents are available at no charge by visiting EDGAR on the SEC website at http://www.sec.gov. When available, copies of the preliminary prospectus supplement, the prospectus supplement and the accompanying base prospectus related to the Offering may be obtained from the following firm at the address set forth below:
J.P. Morgan Securities LLC
c/o Broadridge Financial Solutions
1155 Long Island Avenue
Edgewood, NY 11711
1-866-803-9204
This news release shall not constitute an offer to sell or a solicitation of an offer to buy the securities described above, nor shall there be any sale of, or any solicitation of an offer to buy, these securities in any state or jurisdiction in which such offer, solicitation or sale of these securities would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction. The securities are being offered by means of a prospectus supplement and accompanying prospectus and only to such persons and in such jurisdictions as is permitted under applicable law. The Tender Offers are made subject to the terms of an offer to purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers are deemed to be made on behalf of the Company by the dealer manager or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing.
Forward-Looking Statements
This news release includes forward-looking statements as defined under federal law, including those related to the Offering, the proposed use of proceeds and expected settlement date. There can be no assurance that such expectation or belief will result or be achieved. The Company's future actions and results can and will be affected by a variety of risks and other matters including, but not limited to, changes in commodity prices; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws applicable to the Company's 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 the Company's business generally as set forth in its filings with the SEC. Unless legally required, the Company undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.
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SOURCE Southwestern Energy Company
HOUSTON, Sept. 11, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced that it is commencing, subject to market conditions, a registered underwritten public offering (the "Offering") of $1.15 billion aggregate principal amount of senior notes, consisting of a series of senior, unsecured notes due 2026 (the "2026 Notes") and a series of senior, unsecured notes due 2027 (the "2027 Notes" and, together with the 2026 Notes, the "Notes").
The Company intends to use approximately $327 million of the net proceeds from the Offering to repay in full and terminate its 2015 Amended and Restated Term Loan with various lenders and Bank of America, N.A., as administrative agent and lender, and the remaining net proceeds of the Offering, together with cash on hand, to fund the concurrently announced tender offers to purchase for cash, subject to certain conditions, (i) any and all of the Company's 4.05% Senior Notes due 2020 (the "2020 Notes") and (ii) subject to certain limits, up to $100 million of each of the Company's 4.10% Senior Notes due 2022 and 4.95% Senior Notes due 2025 subject to the applicable priority levels and caps (collectively, the "Tender Offers"). If the Tender Offers are not consummated, or the aggregate amount of securities tendered in the Tender Offers and accepted for payment is less than the net proceeds of the Offering dedicated for that purpose, the Company will use the remainder of the net proceeds for other repayments of indebtedness, subject to the terms of the Company's credit facilities.
J.P. Morgan Securities LLC; Citigroup Global Markets Inc.; MUFG Securities Americas Inc.; BofA Merrill Lynch; Credit Agricole Securities (USA) Inc.; Mizuho Securities USA LLC; RBC Capital Markets, LLC and Wells Fargo Securities, LLC are acting as joint book-running managers for the Offering. The Offering is being made under an automatic shelf registration statement on Form S-3 (Registration No. 333-208074) filed by the Company with the Securities and Exchange Commission ("SEC") and only by means of a prospectus supplement and accompanying prospectus. A preliminary prospectus supplement has been filed with the SEC to which this communication relates. Prospective investors should read the preliminary prospectus supplement and the accompanying prospectus included in the registration statement and other documents the Company has filed with the SEC for more complete information about the Company and the Offering. These documents are available at no charge by visiting EDGAR on the SEC website at http://www.sec.gov. When available, copies of the preliminary prospectus supplement, the prospectus supplement and the accompanying base prospectus related to the Offering may be obtained from the following firm at the address set forth below:
J.P. Morgan Securities LLC c/o Broadridge Financial Solutions 1155 Long Island Avenue Edgewood, NY 11711 1-866-803-9204 |
This news release shall not constitute an offer to sell or a solicitation of an offer to buy the securities described above, nor shall there be any sale of, or any solicitation of an offer to buy, these securities in any state or jurisdiction in which such offer, solicitation or sale of these securities would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction. The securities are being offered by means of a prospectus supplement and accompanying prospectus and only to such persons and in such jurisdictions as is permitted under applicable law. The Tender Offers are made subject to the terms of an offer to purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers are deemed to be made on behalf of the Company by the dealer manager or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing.
Forward-Looking Statements
This news release includes forward-looking statements as defined under federal law, including those related to the Offering and the proposed use of proceeds. There can be no assurance that such expectation or belief will result or be achieved. The Company's future actions and results can and will be affected by a variety of risks and other matters including, but not limited to, changes in commodity prices; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws applicable to the Company's 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 the Company's business generally as set forth in its filings with the SEC. Unless legally required, the Company undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-commences-public-offering-of-115-billion-of-senior-notes-300516938.html
SOURCE Southwestern Energy Company
HOUSTON, Sept. 11, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced that it has commenced offers to purchase for cash (collectively, the "Tender Offers" and each a "Tender Offer") its outstanding senior notes listed in the table below, upon the terms and conditions described in the Company's Offer to Purchase dated September 11, 2017 (the "Offer to Purchase").
Aggregate |
Dollars per U.S. $1,000 Principal | ||||||
Title of Notes |
CUSIP Number |
Maximum Sub-Cap (U.S. $) |
Acceptance |
Tender Offer |
Early Tender |
Total Consideration(1)(2) | |
Any and All Tender Offer Notes: |
|||||||
4.05% Senior Notes due 2020(3) |
845467AK5 |
$850,000,000 |
N/A |
N/A |
$1,020.00 |
$50.00 |
$1,070.00 |
Maximum Tender Offer Notes: |
|||||||
4.10% Senior Notes due 2022 |
845467AF6; 845867AH2; U84517AB4 |
$1,000,000,000 |
$100,000,000(4) |
1 |
$910.00 |
$50.00 |
$960.00 |
4.95% Senior Notes due 2025(3) |
845467AL3 |
$1,000,000,000 |
$100,000,000(4) |
2 |
$955.00 |
$50.00 |
$1,005.00 |
________________ | |
(1) |
Does not include accrued interest, which will also be payable to but not including the applicable settlement date. |
(2) |
Includes the Early Tender Premium. |
(3) |
In February and June 2016, Moody's and S&P downgraded certain senior notes of the Company, increasing the interest rates by 175 basis points effective July 2016. As a result of downgrades, the interest rate increased to 5.80% for the 2020 Notes and to 6.70% for the 2025 Notes. |
(4) |
The Maximum Aggregate Purchase Price, excluding Accrued Interest, for the Maximum Tender Offer Notes (subject to increase by the Company) will be the Threshold Amount ($800 million) less the aggregate purchase price paid for the 2020 Notes accepted for purchase in the Any and All Tender Offer, excluding Accrued Interest. |
Specifically, the Company is offering to purchase any and all 4.05% senior notes due 2020 (the "2020 Notes") and up to an amount subject to the respective Sub-Caps and priorities (as described below), excluding accrued interest, equal to $800 million (subject to increase by the Company, the "Threshold Amount") less the aggregate purchase price paid for the 2020 Notes accepted for purchase, excluding accrued interest (as it may be increased by the Company, the "Maximum Aggregate Purchase Price") of the 4.10% senior notes due 2022 (the "2022 Notes) and 4.95% senior notes due 2025 (the "2025 Notes" and, together with the 2022 Notes, the "Maximum Tender Offer Notes, and collectively with the 2020 Notes and 2022 Notes, the "Notes"). The Tender Offer for the 2020 Notes is referred to herein as the "Any and All Tender Offer" and the Tender Offers for the Maximum Tender Offer Notes are referred to as the "Maximum Tender Offers".
The Company intends to purchase any and all 2020 Notes validly tendered and not validly withdrawn. Subject to the Maximum Aggregate Purchase Price and/or the Sub-Caps (as defined below, subject to increase by the Company), the amount of a series of Maximum Tender Offer Notes that is purchased in the Maximum Tender Offers on the applicable settlement date will be based on the order of priority (the "Acceptance Priority Level") for such series of Maximum Tender Offer Notes set forth in the table above, subject to the proration arrangements applicable to the Maximum Tender Offers. Subject to the Maximum Aggregate Purchase Price, the maximum aggregate purchase price (subject to increase by the Company, the "2022 Notes Sub-Cap") of the 2022 Notes to be paid by the Company will also be limited to $100 million and the maximum aggregate purchase price (subject to increase by the Company, the "2025 Notes Sub-Cap" and together with the 2022 Notes Sub-Cap, the "Sub-Caps") to paid by the Company for the 2025 Notes will also be limited to $100 million.
The Tender Offers will expire at 12:00 midnight, New York City time, at the end of the day on October 6, 2017, unless extended or terminated by the Company (the "expiration date"). No tenders submitted after the expiration date will be valid. Subject to the terms and conditions of the Tender Offers, the consideration for each $1,000 principal amount of the Notes validly tendered and accepted for purchase pursuant to the Tender Offers will be the applicable tender offer consideration set forth in the above table (with respect to each series of Notes, the "Tender Offer Consideration"). Holders of Notes that are validly tendered prior to 5:00 p.m., New York City time, on September 22, 2017 (subject to extension, the "early tender time") and accepted for purchase pursuant to the applicable Tender Offer will receive the total consideration that includes the early tender premium for such series of Notes set forth in the table above (the "Early Tender Premium" and, together with the applicable Tender Offer Consideration, the "Total Consideration"). Holders of Notes tendering their Notes after the early tender time will not be eligible to receive the Early Tender Premium. All Notes validly tendered and accepted for purchase pursuant to the Tender Offers will also receive accrued and unpaid interest on such Notes from the last interest payment date with respect to those Notes to, but not including, the applicable settlement date.
Tendered 2020 Notes may be withdrawn from the Tender Offers prior to 5:00 p.m., New York City time, on September 22, 2017, unless extended by the Company. Holders of Notes who tender their Notes after the applicable withdrawal deadline, but prior to the expiration date, may not withdraw their tendered Notes. The Company reserves the right, but is under no obligation, to increase the Maximum Aggregate Purchase Price, the Threshold Amount or the Sub-Caps at any time, subject to applicable law. If the Company increases the Maximum Aggregate Purchase Price, the Threshold Amounts or the Sub-Caps, it does not expect to extend the withdrawal deadlines, subject to applicable law.
The Company reserves the right, but is under no obligation, at any point following the early tender time and before the expiration date, to accept for purchase any 2020 Notes validly tendered prior to the early tender time. The early settlement date will be limited to 2020 Notes tendered prior to the early tender time, will be determined at the Company's option and is currently expected to occur on September 25, 2017, subject to all conditions to the Any and All Tender Offer having been either satisfied or waived by the Company as of the early settlement date. The Company will purchase any remaining 2020 Notes and, subject to the Maximum Aggregate Purchase Price, the Threshold Amount, the Sub-Caps and proration, and 2022 Notes and 2025 Notes that have been validly tendered and accepted in the applicable Tender Offer prior to the expiration date promptly following the expiration date. The final settlement date is expected to occur on October 10, 2017, the first business day following the expiration date.
If an aggregate principal amount of 2020 Notes validly tendered prior to or subsequent to the early tender time such that the aggregate purchase price for such Notes equals or exceeds the Threshold Amount, holders who validly tender 2022 Notes or 2025 Notes will not have any of their Notes accepted for purchase. Acceptance for tenders of Notes of a series may be subject to proration if the aggregate principal amount of such series of Notes validly tendered would result in an aggregate purchase price that exceeds the applicable Sub-Cap.
As part of the Tender Offers, prior to the early tender time, the Company is also soliciting consents (the "Consent Solicitation") from the holders of the 2020 Notes for certain proposed amendments that would, among other things, amend certain restrictive covenants contained in the indenture governing the 2020 Notes (the "Proposed Amendments"). Adoption of the Proposed Amendments with respect to the 2020 Notes requires the consent of the holders of at least a majority of the outstanding principal amount of the 2020 Notes. Each holder tendering 2020 Notes prior to the early tender time will be deemed to have consented to the Proposed Amendments and holders of 2020 Notes may not deliver consents to the Proposed Amendments without tendering their 2020 Notes. If the Proposed Amendments become operative with respect to the 2020 Notes, Holders of the 2020 Notes that do not tender their 2020 Notes prior to the expiration date, or at all, will be bound by the Proposed Amendments, meaning that the 2020 Notes will no longer have the benefit of the existing terms of certain covenants contained in the Indenture. In addition, such Holders will not receive either the Tender Offer Consideration or the Early Tender Premium.
The Tender Offers are not conditioned upon the tender of any minimum principal amount of Notes of any series nor on the delivery of a number of consents required to amend the indenture with respect to the 2020 Notes. However, the Tender Offers and Consent Solicitation are subject to, and conditioned upon, the satisfaction or waiver of certain conditions described in the Offer to Purchase, including the Company's concurrently announced offering of senior notes (the "notes offering") resulting in gross proceeds of at least $1.15 billion to the Company.
The Company intends to fund the Tender Offers, including accrued and unpaid interest and fees and expenses payable in connection with the Tender Offers, with proceeds from the notes offering and cash on hand.
The purpose of the Tender Offers is to retire debt. If the Tender Offers are not consummated, or if the amount of Notes accepted for purchase in the Tender Offers results in the payment of less than the Maximum Aggregate Purchase Price, the Company may use the remaining amount of proceeds from the notes offering originally dedicated to the Tender Offers to repay or retire other outstanding debt.
J.P. Morgan Securities LLC is the Dealer Manager in the Tender Offers and Consent Solicitation. D.F. King & Co., Inc. has been retained to serve as the Tender Agent and Information Agent for the Tender Offers and Consent Solicitation. Persons with questions regarding the Tender Offers and Consent Solicitation should contact J.P. Morgan Securities LLC at (toll free) (866) 834-4666 or (collect) (212) 834-8553. Requests for the Offer to Purchase should be directed to D.F. King & Co., Inc. at (toll free) (866) 406-2283 or by email to swn@dfking.com.
None of the Company, the dealer manager, the Tender Agent and Information Agent, the trustees under the indentures governing the Notes or any of their respective affiliates is making any recommendation as to whether holders should tender any Notes in response to the Tender Offers and Consent Solicitation. Holders must make their own decision as to whether to participate in the Tender Offers and Consent Solicitation, and, if so, the principal amount of Notes to tender.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Tender Offers are being made only pursuant to the Offer to Purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers will be deemed to be made on behalf of the Company by the Dealer Managers, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-cash-tender-offers-for-senior-notes-300516937.html
SOURCE Southwestern Energy Company
HOUSTON, Aug. 3, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE:SWN) today announced that David Cecil will join the company as its Executive Vice President of Corporate Development, responsible for guiding the company's strategic direction and identifying and capitalizing on growth opportunities, including business and commercial development prospects.
Mr. Cecil joins Southwestern Energy from Lazard, where he has served as Managing Director and Head of the North American E&P group since 2012. He has extensive experience advising energy companies on strategy, business development and capital allocation. Previously, Mr. Cecil was Managing Director of Scotia Waterous (USA), the oil and gas arm of Scotiabank, where he led the U.S. energy investment banking practice.
"We are excited about the depth of industry understanding and experience that David brings to our leadership team and the company," said Bill Way, President and Chief Executive Officer of Southwestern Energy. "I have had the pleasure of working closely with David over the past few years on our financial stabilization strategy and implementation plan. He knows SWN very well, and his insights and broad skill set will help align and focus our strategic direction as we capture the significant opportunities that lie ahead."
About Southwestern Energy
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-executive-vice-president-of-corporate-development-300499500.html
SOURCE Southwestern Energy Company
HOUSTON, Aug. 3, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the quarter ended June 30, 2017, along with other recent developments. Highlights include:
"The core tenets of our focused strategy continue to generate value-adding and economic production growth, as demonstrated by our recent enhancement to well productivity and improving capital efficiency, while we invest within our capital plan," said Bill Way, President and Chief Executive Officer of Southwestern Energy. "The application of our operational learnings are driving dramatically improving well results and continue to produce material increases in value and diversification of the portfolio. Our innovative culture and operational excellence, coupled with our commitment to financial discipline, position us to deliver growing shareholder value moving forward."
Financial Results for the Three and Six Months ended June 30 |
|||||||||||
Southwestern Energy Company and Subsidiaries |
|||||||||||
For the three months ended |
For the six months ended | ||||||||||
June 30, |
June 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
(in millions, except per share amounts) |
|||||||||||
Operating income (loss) |
$ |
188 |
$ |
(492) |
$ |
454 |
$ |
(1,592) | |||
Adjusted operating income (loss) (non-GAAP measure) |
$ |
188 |
$ |
(11) |
$ |
454 |
$ |
(13) | |||
Net income (loss) attributable to common stock |
$ |
224 |
$ |
(620) |
$ |
505 |
$ |
(1,779) | |||
Adjusted net income (loss) attributable to common stock (non-GAAP measure) |
$ |
40 |
$ |
(34) |
$ |
127 |
$ |
(66) | |||
Diluted earnings (loss) per share |
$ |
0.45 |
$ |
(1.61) |
$ |
1.02 |
$ |
(4.63) | |||
Adjusted diluted earnings (loss) per share (non-GAAP measure) |
$ |
0.08 |
$ |
(0.09) |
$ |
0.26 |
$ |
(0.17) | |||
Net cash provided by operating activities |
$ |
266 |
$ |
73 |
$ |
578 |
$ |
165 | |||
Net cash flow (non-GAAP measure) |
$ |
250 |
$ |
114 |
$ |
568 |
$ |
261 | |||
Exploration and Production Operating Results |
For the three months ended |
For the six months ended | |||||||||
June 30, |
June 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Production |
|||||||||||
Fayetteville (Bcf) |
82 |
96 |
163 |
199 | |||||||
Northeast Appalachia (Bcf) |
97 |
90 |
184 |
184 | |||||||
Southwest Appalachia (Bcfe) |
43 |
38 |
79 |
78 | |||||||
Other (Bcfe) |
– |
1 |
– |
1 | |||||||
Total production (Bcfe) |
222 |
225 |
426 |
462 | |||||||
% Natural Gas |
90% |
90% |
90% |
90% | |||||||
Average unit costs per Mcfe |
|||||||||||
Lease operating expenses |
$ |
0.89 |
$ |
0.87 |
$ |
0.89 |
$ |
0.88 | |||
General & administrative expenses(1) |
$ |
0.23 |
$ |
0.21 |
$ |
0.22 |
$ |
0.20 | |||
Taxes, other than income taxes(2) |
$ |
0.10 |
$ |
0.09 |
$ |
0.11 |
$ |
0.09 | |||
Full cost pool amortization |
$ |
0.44 |
$ |
0.35 |
$ |
0.42 |
$ |
0.42 |
(1) |
Excludes $11 million and $69 million of restructuring charges for the three and six months ended June 30, 2016, respectively. |
(2) |
Excludes $3 million of restructuring charges for the six months ended June 30, 2016. |
Realized Prices |
For the three months ended |
For the six months ended | |||||||||
June 30, |
June 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Natural Gas Price: |
|||||||||||
NYMEX Henry Hub Price ($/MMBtu)(1) |
$ |
3.18 |
$ |
1.95 |
$ |
3.25 |
$ |
2.02 | |||
Discount to NYMEX(2) |
(0.83) |
(0.74) |
(0.72) |
(0.69) | |||||||
Average realized gas price per Mcf, excluding hedges |
$ |
2.35 |
$ |
1.21 |
$ |
2.53 |
$ |
1.33 | |||
Gain (loss) on settled financial basis derivatives ($/Mcf) |
(0.15) |
0.00 |
(0.08) |
0.01 | |||||||
Gain (loss) on settled commodity derivatives ($/Mcf) |
(0.05) |
0.11 |
(0.10) |
0.06 | |||||||
Average realized gas price per Mcf, including hedges |
$ |
2.15 |
$ |
1.32 |
$ |
2.35 |
$ |
1.40 | |||
Oil Price: |
|||||||||||
WTI oil price ($/Bbl) |
$ |
48.28 |
$ |
45.59 |
$ |
50.10 |
$ |
39.52 | |||
Discount to WTI |
(7.72) |
(13.13) |
(8.02) |
(14.09) | |||||||
Average oil price per Bbl |
$ |
40.56 |
$ |
32.46 |
$ |
42.08 |
$ |
25.43 | |||
NGL Price: |
|||||||||||
Average net realized NGL price per Bbl(3) |
$ |
11.25 |
$ |
6.41 |
$ |
12.22 |
$ |
5.67 | |||
Percentage of WTI |
23% |
14% |
24% |
14% |
(1) |
Based on last day settlement prices from monthly futures contracts. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
(3) |
Includes $0.04 per Bbl and $0.03 per Bbl of realized hedge gains for the three and six months ended June 30, 2017 and the impact of transportation costs. |
Second Quarter of 2017 Financial Results
E&P Segment – The operating income from the Company's E&P segment improved to $146 million for the second quarter of 2017, compared to an operating loss of $549 million during the second quarter of 2016, primarily due to the $470 million impairment of natural gas and oil properties and $11 million in restructuring charges during this period last year. The increase in operating income was primarily due to the absence of impairments and restructuring charges and higher realized natural gas and liquids pricing.
Midstream Segment – Operating income for the Company's Midstream segment, comprised of gathering and marketing activities, was $42 million for the second quarter of 2017, compared to $57 million for the same period in 2016. The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale.
First Six Months of 2017 Financial Results
E&P Segment – The operating income from the Company's E&P segment improved to $371 million for the first six months of 2017, compared to an operating loss of $1.7 billion during the first six months of 2016, primarily due to the $1.5 billion impairment of natural gas and oil properties and $72 million in restructuring charges during this period last year. The increase in operating income was primarily due to the absence of impairments and restructuring charges, higher realized natural gas and liquids pricing and lower operating costs, partially offset by decreased production.
Midstream Segment – Operating income for the Company's Midstream segment, comprised of gathering and marketing activities, was $83 million for the first six months of 2017, compared to $117 million for the same period in 2016, which included $3 million in restructuring charges. The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale.
Capital Structure and Investments – At June 30, 2017, the Company had total debt of approximately $4.4 billion and $3.3 billion in net debt. In the second quarter, the Company retired its remaining 2018 notes and expects to retire the $40 million outstanding of its 2017 notes when they mature in October.
During the first six months of 2017, Southwestern invested a total of $615 million. This included approximately $601 million invested in its E&P business, $12 million invested in its Midstream segment and $2 million invested for corporate and other purposes. Of the $615 million, approximately $56 million was associated with capitalized interest and $51 million was associated with capitalized expenses. The Company remains committed to aligning its capital investments with commodity prices and will adjust activity in order to protect the balance sheet.
Hedging Update
As of August 1, 2017, the Company had approximately 284 Bcf of its second half of 2017 forecasted gas production protected at an average swap or purchased put strike price of $3.02 per Mcf. Including the protected volumes, the Company retained upside exposure on over half of its remaining forecasted 2017 volumes. Additionally, the Company had approximately 407 Bcf of its 2018 forecasted gas production protected at an average swap or purchased put strike price of $2.98 per Mcf, with upside exposure on approximately 72%, or 295 Bcf, of those protected volumes up to $3.39 per Mcf. The Company also had approximately 108 Bcf of its 2019 forecasted gas production protected at an average purchased put strike price of $2.95 with upside exposure up to $3.32 per Mcf.
A detailed breakdown of the Company's natural gas derivative financial instruments as of August 1, 2017 is shown below. Please refer to the Company's 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 |
Swaps |
Sold Puts |
Purchased |
Sold Calls | |||||||||
Financial protection on production |
|||||||||||||
2017 |
|||||||||||||
Fixed price swaps |
168 |
$ |
3.07 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
48 |
– |
– |
2.93 |
3.35 | ||||||||
Three-way costless collars |
68 |
– |
2.29 |
2.97 |
3.30 | ||||||||
Total |
284 |
||||||||||||
2018 |
|||||||||||||
Fixed price swaps |
112 |
$ |
3.00 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
23 |
– |
– |
2.97 |
3.56 | ||||||||
Three-way costless collars |
272 |
– |
2.40 |
2.97 |
3.37 | ||||||||
Total |
407 |
||||||||||||
2019 |
|||||||||||||
Three-way costless collars |
108 |
$ |
– |
$ |
2.50 |
$ |
2.95 |
$ |
3.32 | ||||
Total |
108 |
||||||||||||
Sold call options |
|||||||||||||
2017 |
43 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.68 | ||||
2018 |
63 |
– |
– |
– |
3.50 | ||||||||
2019 |
52 |
– |
– |
– |
3.50 | ||||||||
2020 |
32 |
– |
– |
– |
3.75 | ||||||||
Total |
190 |
Note: Amounts may not sum due to rounding |
As of August 1, 2017, the Company had also taken steps to mitigate the volatility of basis differentials by protecting basis on approximately 210 Bcf of its second half of 2017 forecasted natural gas production at a basis differential to NYMEX natural gas prices of approximately ($0.69) per Mcf, which includes the impact of both physical and financial basis positions. A detailed breakdown of the Company's financial basis positions as of August 1, 2017 is shown below:
Financial basis positions (excludes physical positions) |
Dominion South |
TETCO M3 |
Total | ||||||
Volume |
Basis Diff |
Volume |
Basis Diff |
Volume |
Basis Diff | ||||
2017 |
54 |
($1.13) |
32 |
($0.82) |
86 |
($1.02) | |||
2018 |
18 |
($1.19) |
4 |
$0.87 |
22 |
($0.83) |
E&P Operational Review
During the second quarter of 2017, Southwestern invested a total of approximately $318 million in the E&P business and participated in drilling 26 wells, completed 39 wells, and placed 44 wells to sales.
Three Months Ended June 30, 2017 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) |
97 |
43 |
82 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
114 |
$ |
81 |
$ |
20 | ||
Acquisition and leasehold |
5 |
15 |
− | |||||
Seismic and other |
4 |
1 |
1 | |||||
Capitalized interest and expense |
10 |
32 |
6 | |||||
Total capital investments |
$ |
133 |
$ |
129 |
$ |
27 | ||
Gross operated well count summary |
||||||||
Drilled |
16 |
8 |
1 | |||||
Completed |
19 |
15 |
5 | |||||
Wells to sales |
21 |
15 |
8 | |||||
Realized Price |
||||||||
NYMEX Henry Hub Price ($/MMBtu) |
$ |
3.18 |
$ |
3.18 |
$ |
3.18 | ||
Discount to NYMEX ($/Mcf)(1) |
$ |
(0.95) |
$ |
(0.63) |
$ |
(0.75) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
2.23 |
$ |
2.55 |
$ |
2.43 |
(1) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
During the first six months of 2017, Southwestern invested a total of approximately $601 million in the E&P business and participated in drilling 59 wells, completed 88 wells, and placed 93 wells to sales.
Six Months Ended June 30, 2017 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) |
184 |
79 |
163 | |||||
Gross operated production as of June 30, 2017 (MMcfe/d) |
1,265 |
783 |
1,288 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
211 |
$ |
154 |
$ |
53 | ||
Acquisition and leasehold |
9 |
31 |
− | |||||
Seismic and other |
5 |
1 |
1 | |||||
Capitalized interest and expense |
20 |
64 |
12 | |||||
Total capital investments |
$ |
245 |
$ |
250 |
$ |
66 | ||
Gross operated well count summary |
||||||||
Drilled |
33 |
16 |
9 | |||||
Completed |
39 |
31 |
18 | |||||
Wells to sales |
45 |
28 |
20 | |||||
Realized Price |
||||||||
NYMEX Henry Hub Price ($/MMBtu) |
$ |
3.25 |
$ |
3.25 |
$ |
3.25 | ||
Discount to NYMEX ($/Mcf)(1) |
$ |
(0.70) |
$ |
(0.57) |
$ |
(0.78) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
2.55 |
$ |
2.68 |
$ |
2.47 |
(1) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
Northeast Appalachia – In the second quarter of 2017, the Company placed 21 wells to sales, which had an average lateral length of 5,530 feet and an average cost of $5.1 million per well. The average rate for the first 30 days for the 16 wells that were online for at least 30 days was 12.5 MMcf per day, down from the first quarter of 2017 due to isolated third-party line pressure and infrastructure limitations that are expected to be resolved in the second half of the year. The Company's operations were impacted in the second quarter by a delay in the installation of a third-party gathering line in Susquehanna County that was expected to come online in early 2017 and a third-party compressor station that was unexpectedly taken offline in late June. The gathering line installation is expected to be completed and in service during the fourth quarter of 2017, and the compressor station is expected to be recommissioned within the third quarter of 2017. The Company has taken action to mitigate the effects of these interruptions, including utilizing the availability of its alternate transportation paths.
The Company's Northeast Appalachia results continue to demonstrate the value of innovation and knowledge application while delivering continuous improvement, with the Company achieving some of its best wells ever drilled after seven years of development. The learnings realized from extended laterals, lateral placement, completion intensity and optimized flow techniques represent a step change in how the Company is approaching well design to maximize value. The most recent example is the Seymour 1H, which is demonstrating productivity among the top 10% of the Company's wells drilled to date in Bradford County on a CLAT-adjusted basis. This well, with a lateral length of over 12,000 feet, was successfully drilled over 90% within the targeted interval and delivered an initial production rate of 37.7 MMcf per day. The Seymour 1H is roughly 20 miles away from the successful results that have been demonstrated in 50 Susquehanna County wells using the same enhancements. These results show that these improvements create significant additional value in other areas.
To facilitate further growth, the Company added approximately 140 MMcf per day of new firm takeaway capacity to the portfolio at an average cost of $0.10 per Mcf. The volumes utilizing this capacity will be indexed to Dominion South pricing, which has significantly improved in 2017 based on new infrastructure progress being made. The basis at this hub is expected to continue to improve as additional progress is made later this year and throughout 2018, resulting in enhanced margins as this asset is further developed.
Southwest Appalachia – In the second quarter of 2017, Southwest Appalachia achieved record net operated production rates, surpassing 500 MMcfe per day in June, a growth of 40% since year-end 2016. Southwest Appalachia's assets continue to provide optionality to maximize returns. With the improved liquids pricing being realized, the Company's development activities in 2017 have focused on the wet gas portion of the play. With this focus and the optimization of the portfolio, Southwest Appalachia's cash flow increased by over $35 million compared to the second quarter of 2016. The Company expects NGL prices to strengthen further as a result of new Gulf Coast ethane cracker facilities coming online and continued expansion of ethane and propane export capacity.
Southwestern brought online 15 wells in Southwest Appalachia in the second quarter, 11 of which were both drilled and completed by Southwestern and four of which were drilled by the previous operator. The 11 wells drilled and completed by Southwestern had an average lateral length of 7,627 feet and an average cost of $7.1 million per well. During the second quarter, the Company continued to realize positive results from its completion design testing. In Marshall County, Southwestern placed the Michael Dunn pad to sales in early April. Through 110 days of production, the 4-well pad has cumulatively produced 4 Bcfe and is currently producing at a flat pad rate of 38 MMcfe per day, 44% of which is liquids, with an average flowing casing pressure of 2,400 psi. The Company tested two wells on this pad with enhanced completions and these wells are currently flowing at an average of 1,050 Mcfe per day higher with an additional 250 psi higher flowing casing pressure, indicating improved performance versus the standard design. The Company will continue to monitor these wells to further assess the well productivity and economic improvements resulting from these enhanced designs.
The Company's first Utica well, the O.E. Burge 501H, continues to exhibit strong productivity, with cumulative production of over 2 Bcf in its first six flowing months. The well is currently flowing at a flat rate of 15 MMcf per day with approximately 6,100 psi of casing pressure and the Company plans to hold the well at this rate into 2018 as part of its pressure management program. Additionally, the Company drilled and completed its second Utica well in Washington County, PA and expects to place the well online and have initial results later in the year.
Fayetteville Shale – During the second quarter of 2017, the Company produced 82 Bcf from the Fayetteville Shale, compared to 81 Bcf in the first quarter of 2017, while generating yet another quarter of positive cash flow. The Company's Fayetteville E&P and gathering operations are expected to generate over $425 million of free cash flow in 2017. This cash flow is a key component of the portfolio and supports the growth in the Appalachian basin.
Additionally, the Company placed eight wells to sales focusing on enhancing economics across the play. Six of the wells placed online targeted the Fayetteville and two targeted the Moorefield. The six Fayetteville wells had an average lateral length of 6,674 feet and average costs of $3.4 million per well and an average 30-day rate of 3.1 MMcf per day.
The two Moorefield wells had an average lateral length of 6,519 feet and an average cost of $4.3 million per well. One well continued the previous success of this development and had a 30th-day rate of 5.0 MMcf per day and an initial EUR of 5.2 Bcf. The second well encountered a fault during drilling, increasing the water rate and impacting the early well results. The learnings from these two wells have been incorporated into the Company's geologic model and it plans to continue to progress its learning of the Moorefield with additional results expected throughout the second half of 2017.
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three and six months ended June 30, 2017 and June 30, 2016, and as of June 30, 2017 and December 31, 2016, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net income (loss) attributable to common stock |
$ |
224 |
$ |
(620) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
27 |
− | |||
Impairment of natural gas and oil properties |
− |
470 | |||
Restructuring charges |
− |
11 | |||
(Gain) loss on certain derivatives |
(173) |
108 | |||
Gain on sale of assets, net |
(2) |
(2) | |||
Loss on early extinguishment of debt |
10 |
− | |||
Adjustments due to inventory valuation and other |
(1) |
1 | |||
Adjustments due to discrete tax items(1) |
(108) |
216 | |||
Tax impact on adjustments |
63 |
(218) | |||
Adjusted net income (loss) attributable to common stock |
$ |
40 |
$ |
(34) |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
6 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net income (loss) attributable to common stock |
$ |
505 |
$ |
(1,779) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
57 |
− | |||
Impairment of natural gas and oil properties |
− |
1,504 | |||
Restructuring charges |
− |
75 | |||
(Gain) loss on certain derivatives |
(319) |
129 | |||
Gain on sale of assets, net |
(3) |
(2) | |||
Loss on early extinguishment of debt |
11 |
− | |||
Adjustments due to inventory valuation and other |
(1) |
4 | |||
Adjustments due to discrete tax items(1) |
(242) |
647 | |||
Tax impact on adjustments |
119 |
(644) | |||
Adjusted net income (loss) attributable to common stock |
$ |
127 |
$ |
(66) |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended June 30, | |||||
2017 |
2016 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted earnings (loss) per share |
$ |
0.45 |
$ |
(1.61) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
0.06 |
− | |||
Impairment of natural gas and oil properties |
− |
1.22 | |||
Restructuring charges |
− |
0.03 | |||
(Gain) loss on certain derivatives |
(0.36) |
0.28 | |||
Gain on sale of assets, net |
(0.00) |
(0.01) | |||
Loss on early extinguishment of debt |
0.02 |
– | |||
Adjustments due to inventory valuation and other |
(0.00) |
0.00 | |||
Adjustments due to discrete tax items(1) |
(0.22) |
0.56 | |||
Tax impact on adjustments |
0.13 |
(0.56) | |||
Adjusted diluted earnings (loss) per share |
$ |
0.08 |
$ |
(0.09) |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
6 Months Ended June 30, | |||||
2017 |
2016 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted earnings (loss) per share |
$ |
1.02 |
$ |
(4.63) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
0.11 |
− | |||
Impairment of natural gas and oil properties |
− |
3.91 | |||
Restructuring charges |
− |
0.19 | |||
(Gain) loss on certain derivatives |
(0.64) |
0.34 | |||
Gain on sale of assets, net |
(0.00) |
(0.00) | |||
Loss on early extinguishment of debt |
0.02 |
– | |||
Adjustments due to inventory valuation and other |
(0.00) |
0.01 | |||
Adjustments due to discrete tax items(1) |
(0.49) |
1.68 | |||
Tax impact on adjustments |
0.24 |
(1.67) | |||
Adjusted diluted earnings (loss) per share |
$ |
0.26 |
$ |
(0.17) |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
266 |
$ |
73 | |
Add back: |
|||||
Changes in operating assets and liabilities |
(16) |
17 | |||
Restructuring charges |
− |
24 | |||
Net Cash Flow |
$ |
250 |
$ |
114 | |
6 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
578 |
$ |
165 | |
Add back: |
|||||
Changes in operating assets and liabilities |
(10) |
50 | |||
Restructuring charges |
− |
46 | |||
Net Cash Flow |
$ |
568 |
$ |
261 | |
3 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating income (loss) |
$ |
188 |
$ |
(492) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
470 | |||
Restructuring charges |
– |
11 | |||
Adjusted operating income (loss) |
$ |
188 |
$ |
(11) | |
6 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating income (loss) |
$ |
454 |
$ |
(1,592) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
1,504 | |||
Restructuring charges |
– |
75 | |||
Adjusted operating income (loss) |
$ |
454 |
$ |
(13) | |
3 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
146 |
$ |
(549) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
470 | |||
Restructuring charges |
– |
11 | |||
Adjusted E&P segment operating income (loss) |
$ |
146 |
$ |
(68) | |
6 Months Ended June 30, | |||||
2017 |
2016 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
371 |
$ |
(1,709) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
1,504 | |||
Restructuring charges |
– |
72 | |||
Adjusted E&P segment operating income (loss) |
$ |
371 |
$ |
(133) | |
June 30, |
December 31, | ||||
2017 |
2016 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
4,381 |
$ |
4,653 | |
Subtract: |
|||||
Cash and cash equivalents |
(1,111) |
(1,423) | |||
Net debt |
$ |
3,270 |
$ |
3,230 |
Southwestern management will host a teleconference call on Friday, August 4, 2017 at 10:00 a.m. Eastern to discuss its second quarter 2017 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
Cautionary Note to U.S. Investors – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves. We use the term "EUR" in this release that the SEC's guidelines prohibit us from including in filings with the SEC. The quarterly reserves data included in this release are estimates we prepared that have not been audited by our independent reserve engineers. U.S. investors are urged to consider closely the oil and gas disclosures in our Form 10-K and other reports and filings with the SEC. Copies are available from the SEC and from the Southwestern Energy Company website.
OPERATING STATISTICS (Unaudited) |
|||||||||||
Southwestern Energy Company and Subsidiaries |
|||||||||||
For the three months ended |
For the six months ended | ||||||||||
June 30, |
June 30, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
Exploration & Production |
|||||||||||
Production |
|||||||||||
Gas production (Bcf) |
199 |
203 |
382 |
416 | |||||||
Oil production (MBbls) |
565 |
586 |
1,084 |
1,193 | |||||||
NGL production (MBbls) |
3,316 |
3,136 |
6,324 |
6,512 | |||||||
Total production (Bcfe) |
222 |
225 |
426 |
462 | |||||||
Commodity Prices |
|||||||||||
Average realized gas price per Mcf, including derivatives |
$ |
2.15 |
$ |
1.32 |
$ |
2.35 |
$ |
1.40 | |||
Average realized gas price per Mcf, excluding derivatives |
$ |
2.35 |
$ |
1.21 |
$ |
2.53 |
$ |
1.33 | |||
Average realized oil price per Bbl |
$ |
40.56 |
$ |
32.46 |
$ |
42.08 |
$ |
25.43 | |||
Average realized NGL price per Bbl |
$ |
11.25 |
$ |
6.41 |
$ |
12.22 |
$ |
5.67 | |||
Summary of Derivative Activity in the Statement of Operations |
|||||||||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(39) |
$ |
23 |
$ |
(69) |
$ |
31 | |||
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
174 |
$ |
(108) |
$ |
319 |
$ |
(126) | |||
Average unit costs per Mcfe |
|||||||||||
Lease operating expenses |
$ |
0.89 |
$ |
0.87 |
$ |
0.89 |
$ |
0.88 | |||
General & administrative expenses (1) |
$ |
0.23 |
$ |
0.21 |
$ |
0.22 |
$ |
0.20 | |||
Taxes, other than income taxes (2) |
$ |
0.10 |
$ |
0.09 |
$ |
0.11 |
$ |
0.09 | |||
Full cost pool amortization |
$ |
0.44 |
$ |
0.35 |
$ |
0.42 |
$ |
0.42 | |||
Midstream |
|||||||||||
Volumes marketed (Bcfe) |
264 |
271 |
509 |
550 | |||||||
Volumes gathered (Bcf) |
128 |
154 |
257 |
318 |
(1) |
Excludes $11 million and $69 million of restructuring charges for the three and six months ended June 30, 2016, respectively. |
(2) |
Excludes $3 million of restructuring charges for the six months ended June 30, 2016. |
STATEMENTS OF OPERATIONS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the six months ended | |||||||||||
June 30, |
June 30, | |||||||||||
2017 |
2016 |
2017 |
2016 | |||||||||
(in millions, except share/per share amounts) | ||||||||||||
Operating Revenues |
||||||||||||
Gas sales |
$ |
471 |
$ |
251 |
$ |
974 |
$ |
566 | ||||
Oil sales |
23 |
20 |
46 |
31 | ||||||||
NGL sales |
37 |
20 |
77 |
37 | ||||||||
Marketing |
250 |
196 |
503 |
394 | ||||||||
Gas gathering |
30 |
35 |
57 |
73 | ||||||||
811 |
522 |
1,657 |
1,101 | |||||||||
Operating Costs and Expenses |
||||||||||||
Marketing purchases |
253 |
197 |
504 |
393 | ||||||||
Operating expenses |
164 |
151 |
311 |
316 | ||||||||
General and administrative expenses |
58 |
56 |
108 |
110 | ||||||||
Restructuring charges |
– |
11 |
– |
75 | ||||||||
Depreciation, depletion and amortization |
123 |
107 |
229 |
250 | ||||||||
Impairment of natural gas and oil properties |
– |
470 |
– |
1,504 | ||||||||
Taxes, other than income taxes |
25 |
22 |
51 |
45 | ||||||||
623 |
1,014 |
1,203 |
2,693 | |||||||||
Operating Income (Loss) |
188 |
(492) |
454 |
(1,592) | ||||||||
Interest Expense |
||||||||||||
Interest on debt |
59 |
56 |
117 |
109 | ||||||||
Other interest charges |
3 |
2 |
5 |
4 | ||||||||
Interest capitalized |
(28) |
(41) |
(56) |
(82) | ||||||||
34 |
17 |
66 |
31 | |||||||||
Gain (Loss) on Derivatives |
134 |
(85) |
250 |
(99) | ||||||||
Loss on Early Extinguishment of Debt |
(10) |
– |
(11) |
– | ||||||||
Other Income (Loss), Net |
6 |
– |
8 |
(3) | ||||||||
Income (Loss) Before Income Taxes |
284 |
(594) |
635 |
(1,725) | ||||||||
Benefit for Income Taxes |
||||||||||||
Deferred |
– |
(1) |
– |
– | ||||||||
Net Income (Loss) |
284 |
(593) |
635 |
(1,725) | ||||||||
Mandatory convertible preferred stock dividend |
27 |
27 |
54 |
54 | ||||||||
Participating securities - mandatory convertible preferred stock |
33 |
– |
76 |
– | ||||||||
Net Income (Loss) Attributable to Common Stock |
$ |
224 |
$ |
(620) |
$ |
505 |
$ |
(1,779) | ||||
Earnings (Loss) Per Common Share |
||||||||||||
Basic |
$ |
0.45 |
$ |
(1.61) |
$ |
1.02 |
$ |
(4.63) | ||||
Diluted |
$ |
0.45 |
$ |
(1.61) |
$ |
1.02 |
$ |
(4.63) | ||||
Weighted Average Common Shares Outstanding | ||||||||||||
Basic |
496,419,815 |
385,594,815 |
494,753,391 |
384,232,831 | ||||||||
Diluted |
498,224,599 |
385,594,815 |
496,627,843 |
384,232,831 |
BALANCE SHEETS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
June 30, |
December 31, | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,579 |
$ |
1,872 | ||
Property and equipment |
25,108 |
24,489 | ||||
Less: Accumulated depreciation, depletion and amortization |
(19,767) |
(19,534) | ||||
Total property and equipment, net |
5,341 |
4,955 | ||||
Other long-term assets |
230 |
249 | ||||
Total assets |
7,150 |
7,076 | ||||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
821 |
1,064 | ||||
Long-term debt |
4,341 |
4,612 | ||||
Pension and other postretirement liabilities |
46 |
49 | ||||
Other long-term liabilities |
369 |
434 | ||||
Total liabilities |
5,577 |
6,159 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 505,893,345 shares as of June 30, 2017 (does not include 3,346,738 shares issued on July 17, 2017 on account of a dividend declared on June 21, 2017) and 495,248,369 as of December 31, 2016 |
5 |
5 | ||||
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of June 30, 2017 and December 31, 2016, conversion in January 2018 |
– |
– | ||||
Additional paid-in capital |
4,697 |
4,677 | ||||
Accumulated deficit |
(3,090) |
(3,725) | ||||
Accumulated other comprehensive loss |
(38) |
(39) | ||||
Common stock in treasury; 31,269 shares as of June 30, 2017 and December 31, 2016, respectively |
(1) |
(1) | ||||
Total equity |
1,573 |
917 | ||||
Total liabilities and equity |
$ |
7,150 |
$ |
7,076 |
STATEMENTS OF CASH FLOWS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
For the six months ended | ||||||
June 30, | ||||||
2017 |
2016 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities |
||||||
Net income (loss) |
$ |
635 |
$ |
(1,725) | ||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
||||||
Depreciation, depletion and amortization |
229 |
250 | ||||
Impairment of natural gas and oil properties |
– |
1,504 | ||||
Amortization of debt issuance costs |
4 |
4 | ||||
(Gain) loss on derivatives, unsettled |
(319) |
129 | ||||
Stock-based compensation |
12 |
17 | ||||
Restructuring charges |
– |
29 | ||||
Loss on early extinguishment of debt |
11 |
– | ||||
Other |
(4) |
7 | ||||
Change in assets and liabilities |
10 |
(50) | ||||
Net cash provided by operating activities |
578 |
165 | ||||
Cash Flows From Investing Activities |
||||||
Capital investments |
(619) |
(241) | ||||
Proceeds from sale of property and equipment |
12 |
54 | ||||
Other |
1 |
1 | ||||
Net cash used in investing activities |
(606) |
(186) | ||||
Cash Flows From Financing Activities |
||||||
Payments on short-term debt |
(287) |
(1) | ||||
Payments on revolving credit facility |
– |
(3,268) | ||||
Borrowings under revolving credit facility |
– |
3,152 | ||||
Payments on commercial paper |
– |
(242) | ||||
Borrowings under commercial paper |
– |
242 | ||||
Change in bank drafts outstanding |
3 |
(21) | ||||
Proceeds from issuance of long-term debt |
– |
1,191 | ||||
Debt issuance costs |
– |
(16) | ||||
Preferred stock dividend |
– |
(27) | ||||
Other |
– |
(6) | ||||
Net cash provided by (used in) financing activities |
(284) |
1,004 | ||||
Increase (decrease) in cash and cash equivalents |
(312) |
983 | ||||
Cash and cash equivalents at beginning of year |
1,423 |
15 | ||||
Cash and cash equivalents at end of period |
$ |
1,111 |
$ |
998 |
SEGMENT INFORMATION (Unaudited) |
|||||||||||||||
Southwestern Energy Company and Subsidiaries |
|||||||||||||||
Exploration |
Midstream |
Other |
Eliminations |
Total | |||||||||||
(in millions) | |||||||||||||||
Three months ended June 30, 2017 |
|||||||||||||||
Revenues |
$ |
526 |
$ |
822 |
$ |
– |
$ |
(537) |
$ |
811 | |||||
Marketing purchases |
– |
731 |
– |
(478) |
253 | ||||||||||
Operating expenses |
200 |
23 |
– |
(59) |
164 | ||||||||||
General and administrative expenses |
50 |
8 |
– |
– |
58 | ||||||||||
Depreciation, depletion and amortization |
107 |
16 |
– |
– |
123 | ||||||||||
Taxes, other than income taxes |
23 |
2 |
– |
– |
25 | ||||||||||
Operating income |
146 |
42 |
– |
– |
188 | ||||||||||
Capital investments (1) |
318 |
6 |
1 |
– |
325 | ||||||||||
Three months ended June 30, 2016 |
|||||||||||||||
Revenues |
$ |
284 |
$ |
559 |
$ |
– |
$ |
(321) |
$ |
522 | |||||
Marketing purchases |
– |
452 |
– |
(255) |
197 | ||||||||||
Operating expenses |
196 |
21 |
– |
(66) |
151 | ||||||||||
General and administrative expenses |
46 |
10 |
– |
– |
56 | ||||||||||
Restructuring charges |
11 |
– |
– |
– |
11 | ||||||||||
Depreciation, depletion and amortization |
90 |
17 |
– |
– |
107 | ||||||||||
Impairment of natural gas and oil properties |
470 |
– |
– |
– |
470 | ||||||||||
Taxes, other than income taxes |
20 |
2 |
– |
– |
22 | ||||||||||
Operating income (loss) |
(549) |
57 |
– |
– |
(492) | ||||||||||
Capital investments (1) |
73 |
– |
1 |
– |
74 | ||||||||||
Six months ended June 30, 2017 |
|||||||||||||||
Revenues |
$ |
1,089 |
$ |
1,680 |
$ |
– |
$ |
(1,112) |
$ |
1,657 | |||||
Marketing purchases |
– |
1,496 |
– |
(992) |
504 | ||||||||||
Operating expenses |
381 |
50 |
– |
(120) |
311 | ||||||||||
General and administrative expenses |
93 |
15 |
– |
– |
108 | ||||||||||
Depreciation, depletion and amortization |
197 |
32 |
– |
– |
229 | ||||||||||
Taxes, other than income taxes |
47 |
4 |
– |
– |
51 | ||||||||||
Operating income |
371 |
83 |
– |
– |
454 | ||||||||||
Capital investments (1) |
601 |
12 |
2 |
– |
615 | ||||||||||
Six months ended June 30, 2016 |
|||||||||||||||
Revenues |
$ |
620 |
$ |
1,180 |
$ |
– |
$ |
(699) |
$ |
1,101 | |||||
Marketing purchases |
– |
955 |
– |
(562) |
393 | ||||||||||
Operating expenses |
405 |
48 |
– |
(137) |
316 | ||||||||||
General and administrative expenses |
91 |
19 |
– |
– |
110 | ||||||||||
Restructuring charges |
72 |
3 |
– |
– |
75 | ||||||||||
Depreciation, depletion and amortization |
217 |
33 |
– |
– |
250 | ||||||||||
Impairment of natural gas and oil properties |
1,504 |
– |
– |
– |
1,504 | ||||||||||
Taxes, other than income taxes |
40 |
5 |
– |
– |
45 | ||||||||||
Operating income (loss) |
(1,709) |
117 |
– |
– |
(1,592) | ||||||||||
Capital investments (1) |
193 |
2 |
1 |
– |
196 |
(1) |
Capital investments includes increases of $41 million and $27 million for the three months ended June 30, 2017 and 2016, respectively, and decreases of $11 million and $51 million for the six months ended June 30, 2017 and 2016, respectively, relating to the change in accrued expenditures between periods. |
View original content:http://www.prnewswire.com/news-releases/southwestern-energy-announces-second-quarter-2017-financial-and-operating-results-300499498.html
SOURCE Southwestern Energy Company
HOUSTON, July 24, 2017 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2017 Second Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, August 4, 2017, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Second Quarter 2017 Earnings |
When: |
August 4, 2017 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live Webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, June 8, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE:SWN) today announced that R. Craig Owen, Senior Vice President and Chief Financial Officer, has elected to leave Southwestern Energy to accept a new career opportunity with an energy company that does not compete with Southwestern Energy. Mr. Owen will remain in his position and continue to support the Company through late June to assist with a smooth transition. Southwestern Energy is engaging in a search to identify a permanent Chief Financial Officer.
Jennifer Stewart, the Company's Senior Vice President, Tax and Treasury, will fulfill the duties of Chief Financial Officer on an interim basis. Ms. Stewart has been with Southwestern Energy since 2010, and previously served as Vice President, Tax. In her current role, she is responsible for all strategies, operations and policies related to cash management, banking relationships and liability and risk management, along with financial planning and analysis. She also manages all aspects of taxation and tax planning for the Company. She is an attorney licensed with the State Bar of Texas and has been admitted to the Bar of the U.S. Tax Court. Prior to joining Southwestern Energy, Ms. Stewart practiced law at Andrews Kurth Kenyon LLP and Shell Oil Company, and spent 10 years in Ernst & Young's national tax practice.
Bill Way, President and Chief Executive Officer, said, "We are pleased that Jennifer has agreed to serve as CFO on an interim basis to ensure continuity and a seamless transition. Jennifer is a seasoned executive who knows our company well, and I am confident that she will assume these responsibilities with the same commitment, capability and expertise she has demonstrated in her seven years at Southwestern Energy. It is a testament to the strength of our organization to have someone of her caliber step into this role. I look forward to working with her and the rest of our Executive Leadership Team as we continue to build on our momentum and leverage our improving financial strength to deliver additional value to our shareholders."
"On behalf of the Southwestern Energy Board of Directors and Executive Leadership Team, I want to thank Craig for his significant contributions to the Company," Mr. Way continued. "In his nearly nine years with Southwestern Energy in which he served as Controller, Chief Accounting Officer and then as CFO since 2012, Craig worked closely with Jennifer, playing a leading role in our liability management efforts, capital market transactions and other key transactions that helped strengthen our balance sheet and drive growth. We are in a much stronger financial position, which has enabled us to soundly manage through the challenging commodity environment and positioned us to capitalize on future opportunities."
"It has been a true privilege working alongside all of my colleagues at Southwestern Energy, which has an energizing, innovation-driven culture," said Mr. Owen. "I firmly believe Jennifer is the right person to step in as CFO on an interim basis, and I look forward to continuing to work closely with her over the coming weeks. While I'm moving on to the next chapter of my career to pursue a unique opportunity, I remain a shareholder and am confident about the value that is being created from the Company's assets when combined with the leadership team and the highly-talented staff."
About Southwestern Energy
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
Forward-Looking Statements
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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, April 27, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the quarter ended March 31, 2017, along with other recent developments. Highlights include:
"We are off to a very strong start in 2017, building upon the momentum from 2016 and continuing our practice of delivering on commitments," said Bill Way, President and Chief Executive Officer of Southwestern Energy. "We invested well within cash flow during the first quarter and delivered value-adding production growth within our guidance range. The results achieved this quarter demonstrate our position as a market leader, and we anticipate providing additional highlights of our operational excellence throughout the remainder of the year as we progress our development plan and multiple innovative initiatives being tested throughout the portfolio."
First Quarter 2017 Financial Results |
|||||
Southwestern Energy Company and Subsidiaries |
|||||
For the three months ended | |||||
March 31, | |||||
2017 |
2016 | ||||
(in millions, except per share amounts) |
|||||
Operating income (loss) |
$ |
266 |
$ |
(1,100) | |
Adjusted operating income (loss) (non-GAAP measure) |
$ |
266 |
$ |
(2) | |
Net earnings (loss) attributable to common stock |
$ |
281 |
$ |
(1,159) | |
Adjusted net income (loss) attributable to common stock (non-GAAP Measure) |
$ |
87 |
$ |
(32) | |
Earnings (loss) per diluted share |
$ |
0.57 |
$ |
(3.03) | |
Adjusted earnings (loss) per diluted share (non-GAAP measure) |
$ |
0.18 |
$ |
(0.08) | |
Net cash provided by operating activities |
$ |
312 |
$ |
92 | |
Net cash flow (non-GAAP measure) |
$ |
318 |
$ |
147 | |
Exploration and Production First Quarter 2017 Financial Results |
For the three months ended | ||||
March 31, | |||||
2017 |
2016 | ||||
Production |
|||||
Fayetteville (Bcf) |
81 |
103 | |||
Northeast Appalachia (Bcf) |
87 |
94 | |||
Southwest Appalachia (Bcfe) |
36 |
40 | |||
Total production (Bcfe) |
204 |
237 | |||
% Natural Gas |
90% |
90% | |||
Average unit costs per Mcfe |
|||||
Lease operating expenses |
$ |
0.89 |
$ |
0.88 | |
General & administrative expenses |
$ |
0.21 |
$ |
0.19 | |
Taxes, other than income taxes |
$ |
0.12 |
$ |
0.08 | |
Full cost pool amortization |
$ |
0.40 |
$ |
0.49 | |
Realized Prices |
For the three months ended | ||||
March 31, | |||||
2017 |
2016 | ||||
Natural Gas Price: |
|||||
NYMEX Henry Hub Price ($/MMBtu)(1) |
$ |
3.32 |
$ |
2.09 | |
Discount to NYMEX(2) |
$ |
(0.59) |
$ |
(0.65) | |
Average realized gas price per Mcf, excluding hedges |
$ |
2.73 |
$ |
1.44 | |
Gain (loss) on settled financial basis derivatives ($/Mcf) |
$ |
(0.01) |
$ |
0.02 | |
Gain (loss) on settled commodity derivatives ($/Mcf) |
$ |
(0.15) |
$ |
0.02 | |
Average realized gas price per Mcf, including hedges |
$ |
2.57 |
$ |
1.48 | |
Oil Price: |
|||||
WTI Oil Price ($/Bbl) |
$ |
51.91 |
$ |
33.45 | |
Discount to WTI |
$ |
(8.17) |
$ |
(14.80) | |
Average oil price per Bbl |
$ |
43.74 |
$ |
18.65 | |
NGL Price: |
|||||
Average net realized NGL price per Bbl(3) |
$ |
13.28 |
$ |
4.98 | |
Percentage of WTI |
26% |
15% |
(1) |
Based on last day settlement prices from monthly futures contracts. |
(2) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
(3) |
Includes $0.02 per Bbl of realized hedge gains for the first quarter of 2017 and the impact of transportation costs |
First Quarter of 2017 Financial Results
E&P Segment – The operating income from the Company's E&P segment improved to $225 million for the first quarter of 2017, compared to an operating loss of $1.2 billion during the first quarter of 2016, primarily due to a $1.0 billion impairment of natural gas and oil properties and $61 million in restructuring charges during this period last year. Beside the lack of impairments or restructuring charges in the first quarter of 2017, the increase in operating income was primarily due to higher realized natural gas and liquids pricing and lower operating costs partially offset by decreased production. The average price realized for our NGL production, including the effects of derivatives, increased 167% to $13.28 per barrel, or 26% of NYMEX WTI, for the three months ended March 31, 2017, compared to $4.98 per barrel, or 15% of NYMEX WTI, for the same period in 2016. The Company expects NGL prices to remain strong with additional ethane cracker demand and incremental export capacity over the next three years.
Midstream Segment – Operating income for the Company's Midstream segment, comprised of gathering and marketing activities, was $41 million for the first quarter of 2017, compared to $60 million for the same period in 2016, which included $3 million in restructuring charges. The decrease in operating income was largely due to a decrease in volumes gathered, resulting from lower production volumes in the Fayetteville Shale.
Capital Structure and Investments – At March 31, 2017, the Company had total debt of approximately $4.6 billion and $3.2 billion in net debt. In the first quarter, the Company repurchased $25 million of its 7.50% Senior Notes due February 2018. Additionally, the Company today announced its plans to retire the remainder of the 2018 notes and also expects to pay the $40 million outstanding of its notes due in October 2017 when they mature.
During the first quarter of 2017, Southwestern invested a total of $290 million. This included approximately $283 million invested in its E&P business, $6 million invested in its Midstream segment and $1 million invested for corporate and other purposes. Of the $290 million, approximately $28 million was associated with capitalized interest and $25 million was associated with capitalized expenses.
Hedging Update
As of April 25, 2017, the Company had approximately 429 Bcf of its remaining 2017 forecasted gas production protected at an average swap or purchased put strike price of $3.03 per Mcf. Including the protected volumes, the Company retained upside exposure on approximately half of its remaining forecasted 2017 volumes. Additionally, the Company had approximately 336 Bcf of its 2018 forecasted gas production protected at an average swap or purchased put strike price of $2.98 per Mcf, with upside exposure on approximately 80%, or 268 Bcf, of those protected volumes up to $3.38 per Mcf. The Company also had approximately 99 Bcf of its 2019 forecasted gas production protected at an average purchased put strike price of $2.95 with upside exposure up to $3.31 per Mcf.
A detailed breakdown of the Company's natural gas derivative financial instruments as of April 25, 2017 is shown below. Please refer to our 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 |
Swaps |
Sold Puts |
Purchased |
Sold Calls | |||||||||
Financial protection on production |
|||||||||||||
2017 |
|||||||||||||
Fixed price swaps |
262 |
$ |
3.07 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
65 |
– |
– |
2.92 |
3.34 | ||||||||
Three-way costless collars |
102 |
– |
2.29 |
2.97 |
3.30 | ||||||||
Total |
429 |
||||||||||||
2018 |
|||||||||||||
Fixed price swaps |
68 |
$ |
3.02 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
23 |
– |
– |
2.97 |
3.56 | ||||||||
Three-way costless collars |
245 |
– |
2.39 |
2.97 |
3.37 | ||||||||
Total |
336 |
||||||||||||
2019 |
|||||||||||||
Three-way costless collars |
99 |
$ |
– |
$ |
2.50 |
$ |
2.95 |
$ |
3.31 | ||||
Total |
99 |
||||||||||||
Sold call options |
|||||||||||||
2017(1) |
64 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.54 | ||||
2018 |
63 |
– |
– |
– |
3.50 | ||||||||
2019 |
52 |
– |
– |
– |
3.50 | ||||||||
2020 |
32 |
– |
– |
– |
3.75 | ||||||||
Total |
211 |
Note: Amounts may not sum due to rounding. | |
(1) |
Excludes $5 million in premiums paid related to certain call options recognized as a component of derivative assets within current assets on the unaudited condensed consolidated balance sheet. As certain call options settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the unaudited condensed consolidated statement of operations. |
As of April 25, 2017, the Company had also taken steps to mitigate the volatility of basis differentials by protecting basis on approximately 296 Bcf of its 2017 forecasted natural gas production at a basis differential to NYMEX natural gas prices of approximately ($0.73) per Mcf, which includes the impact of both physical and financial basis hedges. A detailed breakdown of the Company's financial basis positions as of April 25, 2017 is shown below:
Financial basis positions (excludes physical positions) |
Dominion South |
TETCO M3 |
Total | ||||||
Volume |
Basis Diff |
Volume |
Basis Diff |
Volume |
Basis Diff | ||||
2017 |
85 |
($1.13) |
53 |
($0.90) |
138 |
($1.04) | |||
2018 |
18 |
($1.19) |
2 |
$0.79 |
20 |
($0.95) |
E&P Operational Review
The Company's proved reserves (unaudited) increased to over 10 Tcf in the first quarter of 2017 based on average prices from the first day of each month from the previous 12 months for Henry Hub natural gas of $2.73 per MMBtu for natural gas, West Texas Intermediate oil of $44.10 per barrel of oil and $10.17 per barrel of total NGLs, adjusted for differentials. Proved undeveloped reserves accounted for approximately 35% of total reserves compared to 1% at December 31, 2016. Additionally, Appalachian reserves attributed to approximately 67% of total reserves compared to approximately 43% at year-end 2016. Proved reserves as of March 31, 2017 had a PV10 value of approximately $3.0 billion and are projected to increase throughout the year based on forward strip pricing.
During the first quarter of 2017, Southwestern invested a total of approximately $283 million in our E&P business, and participated in drilling 33 wells, completed 49 wells, and placed 49 wells to sales.
First Quarter 2017 E&P Division Results |
Appalachia |
Fayetteville | ||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) |
87 |
36 |
81 | |||||
Gross operated production as of March 31, 2017 (MMcfe/d) |
1,273 |
668 |
1,342 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
97 |
$ |
73 |
$ |
33 | ||
Acquisition and leasehold |
4 |
16 |
− | |||||
Seismic and other |
1 |
− |
− | |||||
Capitalized interest and expense |
10 |
32 |
6 | |||||
Total capital investments |
$ |
112 |
$ |
121 |
$ |
39 | ||
Gross operated well count summary |
||||||||
Drilled |
17 |
8 |
8 | |||||
Completed |
20 |
16 |
13 | |||||
Wells to sales |
24 |
13 |
12 | |||||
Realized Price |
||||||||
NYMEX Henry Hub Price ($/MMBtu) |
$ |
3.32 |
$ |
3.32 |
$ |
3.32 | ||
Discount to NYMEX ($/Mcf) (1) |
$ |
(0.42) |
$ |
(0.46) |
$ |
(0.80) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
2.90 |
$ |
2.86 |
$ |
2.52 |
(1) |
This discount includes a basis differential, physical basis sales, third-party transportation charges and fuel charges and excludes financial basis hedges. |
Northeast Appalachia – In the first quarter of 2017, the Company placed 24 wells to sales that had an average lateral length of 5,836 feet and an average cost of $5.6 million per well. The average rate for the first 30 days for the 15 of these wells that were online for at least 30 days was 14.8 MMcf per day. In Susquehanna County, the 5-well TNT pad was placed to sales using tighter stage spacing and, after 60 days of production, the average EUR of these wells is expected to be approximately 40% higher than offset wells. To date, the Company has placed 39 wells to sales using increased completion intensity and optimized flow techniques which have resulted in a cumulative production increase of over 200% in the first 30 days over offset wells. In addition to the acceleration of volumes resulting from these completion and production method changes, the Company also believes these changes are improving the average EUR by over 25% compared to historical well results in Susquehanna County, creating significant incremental value for shareholders.
In the first quarter of 2017, the Company placed 7 delineation wells to sales in Susquehanna, Tioga, and Wyoming Counties. In Susquehanna County, the Company placed the Webster 4H and Webster 5H to sales with an average lateral length of 10,110 feet and combined maximum rate of 38.2 MMcf per day. These wells are the first wells drilled on the acreage previously acquired in 2015 and are outperforming offset production by over 100%. Based on these results, the Company plans to drill three additional wells which are expected to come online in the third quarter of 2017. Additionally, the Company continued its delineation efforts in Tioga County, where it holds over 20,000 net acres, placing two wells to sales in the first quarter of 2017 and drilling three additional wells. The Lepley pad, placed to sales in January, continues to exhibit strong results. The two Lepley wells had an average rate for the first 30 days online of 13.3 MMcf per day and are expected to continue to improve as compression is added later in the year. The Company also continues to test its acreage in Wyoming County by placing three wells to sales in first quarter of 2017, observing encouraging results on its southern-most pad in the area. Due to the successful results in each of these delineation areas, the Company plans to continue its delineation efforts throughout the year.
Southwest Appalachia – In the first quarter of 2017, Southwestern brought online 13 wells in Southwest Appalachia with an average lateral length of 7,819 feet and an average cost of $7.2 million per well.
The Company continues to perform additional analysis on the O.E. Burge 501H, but early results indicate that this well is in the top quartile of the industry for wells targeting the deep Upper Point Pleasant formation. Based on current assumptions, the EUR is estimated to be in the range of 2.5 to 3.0 Bcf per thousand feet of lateral completed. The O.E. Burge is currently flowing flat at 17 MMcf per day with 8,531 psi of casing pressure and the Company plans to hold the well at this rate to continue its pressure management program.
Additionally, Southwestern placed 5 wells to sales at the end of January that tested tighter stage spacing and increased proppant loading. Three of these test wells were on the GW Rentals pad with two completed at 140' stage spacing and 3,500 pounds of proppant per foot and one completed at 100' stage spacing and 5,000 pounds of proppant per foot. The other two test wells were on the William Ritchea pad and were tested with 140' stage spacing and 3,500 pounds of proppant per foot. Early indications show all five wells performing better than their closest offsets completed with a wider stage spacing and lower pounds of proppant per foot. To date, the well results show the 140' and 100' stage spaced wells performing similarly and the Company will continue to monitor these wells to determine if there are long-term performance enhancements at the tighter stage spacing. The completion testing program and the accelerated learnings from these tests are expected to create significant value for future development activity.
Fayetteville Shale – During the first quarter of 2017, the Company placed 12 wells to sales, which included 7 wells from a Moorefield pad. These seven wells had an average lateral length of 6,442 feet and estimated average EUR of 6.5 Bcf with an average cost of $3.8 million per well. These wells had an average initial production rate of 6.8 MMcf per day and an average 30th day rate of 5.1 MMcf per day. These results confirm the Company's understanding of the play and demonstrate the Moorefield's potential to improve economics in the play. The Company plans to place an additional 8 Moorefield wells to sales through the remainder of 2017.
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three months ended March 31, 2017 and March 31, 2016, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended March 31, | |||||||
2017 |
2016 | ||||||
(in millions) | |||||||
Net income (loss) attributable to common stock: |
|||||||
Net income (loss) attributable to common stock |
$ |
281 |
$ |
(1,159) | |||
Add back: |
|||||||
Participating securities – mandatory convertible preferred stock |
30 |
− | |||||
Impairment of natural gas and oil properties |
− |
1,034 | |||||
Restructuring charges |
− |
64 | |||||
(Gain) loss on certain derivatives |
(146) |
21 | |||||
(Gain) loss on sale of assets |
(1) |
− | |||||
Loss on early extinguishment of debt |
1 |
− | |||||
Adjustments due to inventory valuation |
− |
3 | |||||
Adjustments due to discrete tax items(1) |
(134) |
431 | |||||
Tax impact on adjustments |
56 |
(426) | |||||
Adjusted net income (loss) attributable to common stock |
$ |
87 |
$ |
(32) | |||
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended March 31, | |||||
2017 |
2016 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted earnings (loss) per share |
$ |
0.57 |
$ |
(3.03) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
0.06 |
− | |||
Impairment of natural gas and oil properties |
− |
2.70 | |||
Restructuring charges |
− |
0.17 | |||
(Gain) loss on certain derivatives |
(0.30) |
0.05 | |||
(Gain) loss on sale of assets |
(0.00) |
– | |||
Loss on early extinguishment of debt |
0.00 |
– | |||
Adjustments due to inventory valuation |
− |
0.01 | |||
Adjustments due to discrete tax items(1) |
(0.27) |
1.13 | |||
Tax impact on adjustments |
0.12 |
(1.11) | |||
Adjusted diluted earnings (loss) per share |
$ |
0.18 |
$ |
(0.08) |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments associated with the valuation allowance against deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended March 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
312 |
$ |
92 | |
Add back: |
|||||
Changes in operating assets and liabilities |
6 |
33 | |||
Restructuring charges |
− |
22 | |||
Net Cash Flow |
$ |
318 |
$ |
147 | |
3 Months Ended March 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating income (loss) |
$ |
266 |
$ |
(1,100) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
1,034 | |||
Restructuring charges |
– |
64 | |||
Adjusted operating income (loss) |
$ |
266 |
$ |
(2) | |
3 Months Ended March 31, | |||||
2017 |
2016 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
225 |
$ |
(1,160) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
1,034 | |||
Restructuring charges |
– |
61 | |||
Adjusted E&P segment operating income (loss) |
$ |
225 |
$ |
(65) | |
March 31, |
December 31, | ||||
2017 |
2016 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
4,630 |
$ |
4,653 | |
Subtract: |
|||||
Cash and cash equivalents |
(1,382) |
(1,423) | |||
Net debt |
$ |
3,248 |
$ |
3,230 |
Southwestern management will host a teleconference call on Friday, April 28, 2017 at 10:00 a.m. Eastern to discuss its first quarter 2017 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
Cautionary Note to U.S. Investors – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves. We use the term "EUR" in this release that the SEC's guidelines prohibit us from including in filings with the SEC. The quarterly reserves data included in this release are estimates we prepared that have not been audited by our independent reserve engineers. U.S. investors are urged to consider closely the oil and gas disclosures in our Form 10-K and other reports and filings with the SEC. Copies are available from the SEC and from the Southwestern Energy Company website.
OPERATING STATISTICS (Unaudited) |
|||||
Southwestern Energy Company and Subsidiaries |
|||||
For the three months ended | |||||
March 31, | |||||
2017 |
2016 | ||||
Exploration & Production |
|||||
Production |
|||||
Gas production (Bcf) |
183 |
213 | |||
Oil production (MBbls) |
519 |
607 | |||
NGL production (MBbls) |
3,008 |
3,376 | |||
Total production (Bcfe) |
204 |
237 | |||
Commodity Prices |
|||||
Average realized gas price per Mcf, including derivatives |
$ |
2.57 |
$ |
1.48 | |
Average realized gas price per Mcf, excluding derivatives |
$ |
2.73 |
$ |
1.44 | |
Average realized oil price per Bbl |
$ |
43.74 |
$ |
18.65 | |
Average realized NGL price per Bbl |
$ |
13.28 |
$ |
4.98 | |
Summary of Derivative Activity in the Statement of Operations |
|||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(30) |
$ |
8 | |
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
145 |
$ |
(18) | |
Average unit costs per Mcfe |
|||||
Lease operating expenses |
$ |
0.89 |
$ |
0.88 | |
General & administrative expenses (1) |
$ |
0.21 |
$ |
0.19 | |
Taxes, other than income taxes (2) |
$ |
0.12 |
$ |
0.08 | |
Full cost pool amortization |
$ |
0.40 |
$ |
0.49 | |
Midstream |
|||||
Volumes marketed (Bcfe) |
245 |
279 | |||
Volumes gathered (Bcf) |
129 |
165 |
(1) |
Excludes $58 million of restructuring charges in 2016. |
(2) |
Excludes $3 million of restructuring charges in 2016. |
STATEMENTS OF OPERATIONS (Unaudited) |
|||||
Southwestern Energy Company and Subsidiaries |
|||||
For the three months ended | |||||
March 31, | |||||
2017 |
2016 | ||||
Operating Revenues |
|||||
Gas sales |
$ |
503 |
$ |
315 | |
Oil sales |
23 |
11 | |||
NGL sales |
40 |
17 | |||
Marketing |
253 |
198 | |||
Gas gathering |
27 |
38 | |||
846 |
579 | ||||
Operating Costs and Expenses |
|||||
Marketing purchases |
251 |
196 | |||
Operating expenses |
147 |
165 | |||
General and administrative expenses |
50 |
54 | |||
Restructuring charges |
– |
64 | |||
Depreciation, depletion and amortization |
106 |
143 | |||
Impairment of natural gas and oil properties |
– |
1,034 | |||
Taxes, other than income taxes |
26 |
23 | |||
580 |
1,679 | ||||
Operating Income (Loss) |
266 |
(1,100) | |||
Interest Expense |
|||||
Interest on debt |
58 |
53 | |||
Other interest charges |
2 |
2 | |||
Interest capitalized |
(28) |
(41) | |||
32 |
14 | ||||
Gain (Loss) on Derivatives |
116 |
(14) | |||
Loss on Early Extinguishment of Debt |
(1) |
– | |||
Other Income (Loss), Net |
2 |
(3) | |||
Income (Loss) Before Income Taxes |
351 |
(1,131) | |||
Provision for Income Taxes |
|||||
Deferred |
– |
1 | |||
– |
1 | ||||
Net Income (Loss) |
351 |
(1,132) | |||
Mandatory convertible preferred stock dividend |
27 |
27 | |||
Participating securities - mandatory convertible preferred stock |
43 |
– | |||
Net Income (Loss) Attributable to Common Stock |
$ |
281 |
$ |
(1,159) | |
Income (Loss) Per Common Share |
|||||
Basic |
$ |
0.57 |
$ |
(3.03) | |
Diluted |
$ |
0.57 |
$ |
(3.03) | |
Weighted Average Common Shares Outstanding | |||||
Basic |
493,068,000 |
382,870,847 | |||
Diluted |
494,494,995 |
382,870,847 |
BALANCE SHEETS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
March 31,
2017 |
December 31, 2016 | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,789 |
$ |
1,872 | ||
Property and equipment |
24,784 |
24,489 | ||||
Less: Accumulated depreciation, depletion and amortization |
(19,641) |
(19,534) | ||||
Total property and equipment, net |
5,143 |
4,955 | ||||
Other long-term assets |
264 |
249 | ||||
Total assets |
7,196 |
7,076 | ||||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
1,121 |
1,064 | ||||
Long-term debt |
4,364 |
4,612 | ||||
Pension and other postretirement liabilities |
47 |
49 | ||||
Other long-term liabilities |
386 |
434 | ||||
Total liabilities |
5,918 |
6,159 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 502,497,469 shares as of March 31, 2017 (does not include 3,346,865 shares issued on April 17, 2017 on account of a dividend declared on March 21, 2017) and 495,248,369 as of December 31, 2016 |
5 |
5 | ||||
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of March 31, 2017 and December 31, 2016, conversion in January 2018 |
– |
– | ||||
Additional paid-in capital |
4,687 |
4,677 | ||||
Accumulated deficit |
(3,374) |
(3,725) | ||||
Accumulated other comprehensive loss |
(39) |
(39) | ||||
Common stock in treasury, 31,269 shares as of March 31, 2017 and December 31, 2016 |
(1) |
(1) | ||||
Total equity |
1,278 |
917 | ||||
Total liabilities and equity |
$ |
7,196 |
$ |
7,076 |
STATEMENTS OF CASH FLOWS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
For the three months ended | ||||||
March 31, | ||||||
2017 |
2016 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities: |
||||||
Net income (loss) |
$ |
351 |
$ |
(1,132) | ||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
||||||
Depreciation, depletion and amortization |
106 |
143 | ||||
Impairment of natural gas and oil properties |
– |
1,034 | ||||
Amortization of debt issuance costs |
2 |
2 | ||||
Deferred income taxes |
– |
1 | ||||
(Gain) Loss on derivatives, net of settlement |
(146) |
21 | ||||
Stock-based compensation |
6 |
9 | ||||
Restructuring charges |
– |
42 | ||||
Loss on early extinguishment of debt |
1 |
– | ||||
Other |
(2) |
5 | ||||
Change in assets and liabilities |
(6) |
(33) | ||||
Net cash provided by operating activities |
312 |
92 | ||||
Cash Flows From Investing Activities: |
||||||
Capital investments |
(340) |
(196) | ||||
Proceeds from sale of property and equipment |
2 |
– | ||||
Other |
4 |
– | ||||
Net cash used in investing activities |
(334) |
(196) | ||||
Cash Flows From Financing Activities: |
||||||
Payments on short-term debt |
(25) |
– | ||||
Payments on revolving credit facility |
– |
(864) | ||||
Borrowings under revolving credit facility |
– |
2,600 | ||||
Payments on commercial paper |
– |
(242) | ||||
Borrowings under commercial paper |
– |
242 | ||||
Change in bank drafts outstanding |
6 |
(19) | ||||
Preferred stock dividend |
– |
(27) | ||||
Other |
– |
(4) | ||||
Net cash provided by (used in) financing activities |
(19) |
1,686 | ||||
Increase (decrease) in cash and cash equivalents |
(41) |
1,582 | ||||
Cash and cash equivalents at beginning of year |
1,423 |
15 | ||||
Cash and cash equivalents at end of period |
$ |
1,382 |
$ |
1,597 |
SEGMENT INFORMATION (Unaudited) |
|||||||||||||||
Southwestern Energy Company and Subsidiaries |
|||||||||||||||
Exploration |
Midstream Services |
Other |
Eliminations |
Total | |||||||||||
(in millions) | |||||||||||||||
Three months ended March 31, 2017 |
|||||||||||||||
Revenues |
$ |
563 |
$ |
858 |
$ |
– |
$ |
(575) |
$ |
846 | |||||
Marketing purchases |
– |
765 |
– |
(514) |
251 | ||||||||||
Operating expenses |
181 |
27 |
– |
(61) |
147 | ||||||||||
General and administrative expenses |
43 |
7 |
– |
– |
50 | ||||||||||
Depreciation, depletion and amortization |
90 |
16 |
– |
– |
106 | ||||||||||
Taxes, other than income taxes |
24 |
2 |
– |
– |
26 | ||||||||||
Operating income |
225 |
41 |
– |
– |
266 | ||||||||||
Capital investments (1) |
283 |
6 |
1 |
– |
290 | ||||||||||
Three months ended March 31, 2016 |
|||||||||||||||
Revenues |
$ |
336 |
$ |
621 |
$ |
– |
$ |
(378) |
$ |
579 | |||||
Marketing purchases |
– |
503 |
– |
(307) |
196 | ||||||||||
Operating expenses |
209 |
27 |
– |
(71) |
165 | ||||||||||
General and administrative expenses |
45 |
9 |
– |
– |
54 | ||||||||||
Restructuring charges |
61 |
3 |
– |
– |
64 | ||||||||||
Depreciation, depletion and amortization |
127 |
16 |
– |
– |
143 | ||||||||||
Impairment of natural gas and oil properties |
1,034 |
– |
– |
– |
1,034 | ||||||||||
Taxes, other than income taxes |
20 |
3 |
– |
– |
23 | ||||||||||
Operating income (loss) |
(1,160) |
60 |
– |
– |
(1,100) | ||||||||||
Capital investments (1) |
120 |
2 |
– |
– |
122 |
(1) |
Capital investments includes decreases of $52 million and $78 million for the three months ended March 31, 2017 and 2016, respectively, relating to the change in accrued expenditures between periods. |
SOURCE Southwestern Energy Company
HOUSTON, April 27, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") announced today that it will redeem all (i) $37,991,000 aggregate principal amount outstanding of its 3.30% Senior Notes due 2018 (the "3.30% 2018 Notes"), (ii) $187,576,000 aggregate principal amount outstanding of its 7.50% Senior Notes due 2018 (the "7.50% 2018 Notes") and (iii) $25,800,000 aggregate principal amount outstanding of its 7.15% Senior Notes due 2018 (the "7.15% 2018 Notes" and, together with the 3.30% 2018 Notes and the 7.50% 2018 Notes, the "Notes") on May 30, 2017, the redemption date for each of the 3.30% 2018 Notes, 7.50% 2018 Notes and 7.15% 2018 Notes (the "Redemption Date").
The redemption price for each series of the Notes will be calculated pursuant to the formula set forth in the applicable indenture governing such series of the Notes.
Additional information concerning the terms and conditions of the redemptions are fully described in the notices distributed to holders of the Notes. Beneficial holders with any questions about the redemptions should contact their respective brokerage firm or financial institution.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
This news release contains forward-looking statements regarding the Company's intention to redeem the Notes. There can be no assurance that such expectation or belief will result or be achieved. The Company's future actions and results can and will be affected by a variety of risks and other matters including, but not limited to, changes in commodity prices; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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, the Company undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.
SOURCE Southwestern Energy Company
HOUSTON, April 17, 2017 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2017 First Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, April 28, 2017, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's First Quarter 2017 Earnings |
When: |
April 28, 2017 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live Webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, March 21, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that an authorized committee of its Board of Directors declared a quarterly dividend of $15.625 per share on its 6.25% Series B Mandatory Convertible Preferred Stock, payable on April 17, 2017, to holders of record on April 1, 2017. This equates to $0.78125 for each depositary share, which represents a 1/20th interest in a share of the Series B preferred stock. The dividend is for the period beginning on January 15, 2017 and ending on April 14, 2017.
The company has elected to pay this dividend in shares of common stock of the company to the extent permitted by the certificate of designations for the Series B preferred stock. Common shares issued will be listed and tradable on the New York Stock Exchange.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, Feb. 23, 2017 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the fourth quarter and the year ended December 31, 2016. Calendar year 2016 highlights include:
"The bold and decisive approach in which we tackled 2016 delivered remarkable results," said Bill Way, President and Chief Executive Officer of Southwestern Energy. "The progress made in improving our financial strength and the operational excellence that facilitated our mid-year resumption of drilling and completion activities has the Company positioned well to create long-term value for our shareholders."
The Company delivered on all of the initiatives promised at the beginning of 2016, which included strengthening the balance sheet and enhancing margins. As a result, the Company extended its liquidity through 2020 and ended the year with total debt of $4.7 billion and net debt of $3.2 billion, reducing its net debt by $1.5 billion compared to the end of 2015. Additionally, the Company was able to reduce cash operating costs, which includes lease operating expense, general and administrative expense and taxes other than income, by $0.04 per Mcfe through a relentless focus on margin enhancements and operational efficiencies. Below is a summary of fourth quarter and full year 2016 results.
Fourth Quarter and Year-end 2016 Financial Results | |||||||||||
Southwestern Energy Company and Subsidiaries | |||||||||||
For the three months ended |
For the year ended | ||||||||||
December 31, |
December 31, | ||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||
(in millions, except per share amounts) |
|||||||||||
Operating income (loss) |
$ |
122 |
$ |
(2,561) |
$ |
(2,195) |
$ |
(6,522) | |||
Adjusted operating income (non-GAAP measure) |
$ |
134 |
$ |
8 |
$ |
215 |
$ |
146 | |||
Net loss attributable to common stock |
$ |
(237) |
$ |
(2,134) |
$ |
(2,751) |
$ |
(4,662) | |||
Adjusted net income (loss) attributable to common stock (non-GAAP measure) |
$ |
39 |
$ |
(6) |
$ |
(7) |
$ |
71 | |||
Loss per share |
$ |
(0.48) |
$ |
(5.58) |
$ |
(6.32) |
$ |
(12.25) | |||
Adjusted earnings (loss) per share (non-GAAP measure) |
$ |
0.08 |
$ |
(0.02) |
$ |
(0.01) |
$ |
0.19 | |||
Net cash provided by operating activities |
$ |
161 |
$ |
353 |
$ |
498 |
$ |
1,580 | |||
Net cash flow (non-GAAP measure) |
$ |
211 |
$ |
306 |
$ |
645 |
$ |
1,468 | |||
Exploration and Production 2016 Financial Results |
For the three months ended |
For the year ended | |||||||||
December 31, |
December 31, | ||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||
Production |
|||||||||||
Fayetteville (Bcf) |
86 |
112 |
375 |
465 | |||||||
Northeast Appalachia (Bcf) |
82 |
97 |
350 |
360 | |||||||
Southwest Appalachia (Bcfe) |
33 |
40 |
148 |
143 | |||||||
Other (Bcfe) |
1 |
- |
2 |
8 | |||||||
Total production (Bcfe) |
202 |
249 |
875 |
976 | |||||||
% Natural Gas |
90% |
91% |
90% |
92% | |||||||
Average unit costs per Mcfe |
|||||||||||
Lease operating expenses |
$ |
0.87 |
$ |
0.91 |
$ |
0.87 |
$ |
0.92 | |||
General & administrative expenses(1) |
$ |
0.27 |
$ |
0.20 |
$ |
0.22 |
$ |
0.21 | |||
Taxes, other than income taxes(2) |
$ |
0.11 |
$ |
0.09 |
$ |
0.10 |
$ |
0.10 | |||
Full cost pool amortization |
$ |
0.30 |
$ |
0.78 |
$ |
0.38 |
$ |
1.00 |
(1) |
Excludes restructuring and other one-time charges for the three months and year ended December 31, 2016, respectively. |
(2) |
Excludes restructuring charges for the year ended December 31, 2016. |
Realized Prices |
For the three months ended |
For the year ended | |||||||||
December 31, |
December 31, | ||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||
Natural Gas Price: |
|||||||||||
NYMEX Henry Hub Price ($/MMBtu)(1) |
$ |
2.98 |
$ |
2.27 |
$ |
2.46 |
$ |
2.66 | |||
Discount to NYMEX(2) |
$ |
(0.98) |
$ |
(0.79) |
$ |
(0.87) |
$ |
(0.75) | |||
Average realized gas price per Mcf, excluding hedges |
$ |
2.00 |
$ |
1.48 |
$ |
1.59 |
$ |
1.91 | |||
Gain (loss) on settled financial basis derivatives ($/Mcf) |
$ |
0.09 |
$ |
0.02 |
$ |
0.03 |
$ |
(0.00) | |||
Gain (loss) on settled commodity derivatives ($/Mcf) |
$ |
(0.02) |
$ |
0.57 |
$ |
0.02 |
$ |
0.46 | |||
Average realized gas price per Mcf, including hedges |
$ |
2.07 |
$ |
2.07 |
$ |
1.64 |
$ |
2.37 | |||
Oil Price: |
|||||||||||
WTI oil price ($/Bbl) |
$ |
49.29 |
$ |
42.18 |
$ |
43.32 |
$ |
48.80 | |||
Discount to WTI |
$ |
(8.11) |
$ |
(14.82) |
$ |
(12.12) |
$ |
(15.55) | |||
Average oil price per Bbl |
$ |
41.18 |
$ |
27.36 |
$ |
31.20 |
$ |
33.25 | |||
NGL Price: |
|||||||||||
Average net realized NGL price per Bbl |
$ |
12.08 |
$ |
7.62 |
$ |
7.46 |
$ |
6.80 | |||
Percentage of WTI |
25% |
18% |
17% |
14% |
(1) |
Based on last day settlement prices from monthly futures contracts. |
(2) |
This discount includes a basis differential, physical basis hedges, third-party transportation charges and fuel charges and excludes financial basis hedges. |
Fourth Quarter of 2016 Financial Results
E&P Segment – The operating income from the Company's E&P segment was $82 million for the fourth quarter of 2016, improved from an operating loss of $2.6 billion during the fourth quarter of 2015 due to a $2.6 billion impairment of natural gas and oil properties during that quarter. Excluding impairments and other one-time charges, adjusted operating income from the Company's E&P segment was $94 million for the fourth quarter of 2016, compared to an adjusted operating loss of $64 million for the same period in 2015. The increase in adjusted operating income was primarily due to lower operating costs and higher realized liquids prices partially offset by decreased production. The decreased production was a result of limited activity in 2016 due to lower natural gas prices.
Midstream Segment – Operating income for the Company's Midstream segment, comprised of gathering and marketing activities, was $40 million for the fourth quarter of 2016, compared to $72 million for the same period in 2015. The decrease in operating income was largely due to a decrease in volumes gathered, resulting from lower production volumes in the Fayetteville Shale.
Full Year 2016 Financial Results
E&P Segment – The operating loss from the Company's E&P segment was $2.4 billion for 2016, compared to an operating loss of $7.1 billion for 2015. The E&P segment recorded a $2.3 billion impairment of natural gas and oil properties for the year ended December 31, 2016 compared to a $7.0 billion impairment for the same period in 2015. Excluding impairments, the improvement in operating loss was primarily due to lower operating costs and expenses and increasing NGL realizations, partially offset by lower realized natural gas prices and decreased production. Adjusted operating income from the Company's E&P segment was $3 million for 2016, compared to an adjusted operating loss of $159 million in 2015.
Midstream Services – Operating income for the Company's Midstream segment was $209 million for 2016, compared to $583 million for the same period in 2015. The decrease in operating income was primarily due to 2015 including a $277 million net gain on sale of assets divested. Adjusted operating income for the Company's Midstream segment was $212 million for 2016 compared to $306 million for the same period in 2015. The decrease in adjusted operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale and the sale of the Company's northeast Pennsylvania gathering assets.
Capital Investments – During 2016, Southwestern invested a total of $648 million. This included approximately $623 million invested in its E&P business, $21 million invested in its Midstream segment and $4 million invested for corporate and other purposes. Of the $648 million, approximately $152 million was associated with capitalized interest and $89 million was associated with capitalized expenses.
2016 Natural Gas and Oil Reserves
Southwestern's estimated proved natural gas and oil reserves totaled approximately 5,253 Bcfe at December 31, 2016, compared to 6,215 Bcfe at the end of 2015. The decrease in the Company's reserves in 2016 was primarily due to downward price revisions associated with decreased commodity prices and 2016 production, partially offset by upward performance revisions and the Company's successful development activity in Northeast Appalachia, Southwest Appalachia and the Fayetteville Shale. The average prices from the first day of each month from the previous twelve months utilized to value the Company's estimated proved natural gas and oil reserves at December 31, 2016 were $2.48 per MMBtu for natural gas, $39.25 per barrel for oil and $6.74 per barrel for NGLs, compared to $2.59 per MMBtu for natural gas, $46.79 per barrel for oil and $6.82 per barrel for NGLs at December 31, 2015. Approximately 93% of the Company's estimated proved reserves were natural gas and 99% were classified as proved developed at year-end 2016, compared to 95% and 93%, respectively, at year-end 2015.
The following table details additional information relating to reserve estimates as of and for the year ended December 31, 2016:
Natural Gas |
Oil |
NGL |
Total | ||||
(Bcf) |
(MBbls) |
(MBbls) |
(Bcfe) | ||||
Proved reserves, beginning of year |
5,917 |
8,753 |
40,947 |
6,215 | |||
Revisions of previous estimates |
(446) |
1,564 |
13,794 |
(354) | |||
Extensions, discoveries and other additions |
198 |
2,417 |
11,576 |
282 | |||
Production |
(788) |
(2,192) |
(12,372) |
(875) | |||
Acquisition of reserves in place |
– |
– |
– |
– | |||
Disposition of reserves in place |
(15) |
(19) |
(14) |
(15) | |||
Proved reserves, end of year |
4,866 |
10,523 |
53,931 |
5,253 | |||
Proved developed reserves: |
|||||||
Beginning of year |
5,474 |
8,753 |
40,947 |
5,772 | |||
End of year |
4,789 |
10,523 |
53,931 |
5,176 |
Note: Amounts may not add due to rounding |
2016 PROVED RESERVES BY DIVISION | ||||||||||
Appalachia |
Fayetteville |
|||||||||
Northeast |
Southwest |
Shale |
Other |
Total | ||||||
Estimated Proved Reserves (Bcfe): |
||||||||||
Reserves, beginning of year |
2,319 |
611 |
3,281 |
4 |
6,215 | |||||
Production |
(350) |
(148) |
(375) |
(2) |
(875) | |||||
Extensions, discoveries and other additions |
81 |
157 |
44 |
– |
282 | |||||
Disposition of reserves in place |
– |
(15) |
– |
– |
(15) | |||||
Price revisions |
(794) |
(127) |
(116) |
– |
(1,037) | |||||
Performance & production revisions |
318 |
199 |
163 |
3 |
683 | |||||
Reserves, end of year |
1,574 |
677 |
2,997 |
5 |
5,253 |
The following table provides an overall and by category summary of the Company's natural gas, oil and NGL reserves as of December 31, 2016 and sets forth 2016 annual information related to production and capital investments for each of its operating areas:
2016 PROVED RESERVES BY CATEGORY AND SUMMARY OPERATING DATA | |||||||||||||||
Appalachia |
Fayetteville |
||||||||||||||
Northeast |
Southwest |
Shale |
Other (1) |
Total | |||||||||||
Estimated Proved Reserves: |
|||||||||||||||
Natural Gas (Bcf): |
|||||||||||||||
Developed (Bcf) |
1,540 |
293 |
2,954 |
2 |
4,789 | ||||||||||
Undeveloped (Bcf) |
34 |
– |
43 |
– |
77 | ||||||||||
1,574 |
293 |
2,997 |
2 |
4,866 | |||||||||||
Crude Oil (MMBbls): |
|||||||||||||||
Developed (MMBbls) |
– |
10.2 |
– |
0.3 |
10.5 | ||||||||||
Undeveloped (MMBbls) |
– |
– |
– |
– |
– | ||||||||||
– |
10.2 |
– |
0.3 |
10.5 | |||||||||||
Natural Gas Liquids (MMBbls): |
|||||||||||||||
Developed (MMBbls) |
– |
53.8 |
– |
0.1 |
53.9 | ||||||||||
Undeveloped (MMBbls) |
– |
– |
– |
– |
– | ||||||||||
– |
53.8 |
– |
0.1 |
53.9 | |||||||||||
Total Proved Reserves (Bcfe): |
|||||||||||||||
Developed (Bcfe) |
1,540 |
677 |
2,954 |
5 |
5,176 | ||||||||||
Undeveloped (Bcfe) |
34 |
– |
43 |
– |
77 | ||||||||||
1,574 |
677 |
2,997 |
5 |
5,253 | |||||||||||
Percent of Total |
30% |
13% |
57% |
0% |
100% | ||||||||||
Percent Proved Developed |
98% |
100% |
99% |
100% |
99% | ||||||||||
Percent Proved Undeveloped |
2% |
0% |
1% |
0% |
1% | ||||||||||
Production (Bcfe) |
350 |
148 |
375 |
2 |
875 | ||||||||||
Capital Investments (millions)(2) |
$ |
204 |
$ |
288 |
$ |
86 |
$ |
19 |
$ |
597 | |||||
Total Gross Producing Wells(3) |
820 |
306 |
4,217 |
16 |
5,359 | ||||||||||
Total Net Producing Wells(3) |
439 |
216 |
2,932 |
13 |
3,600 | ||||||||||
Total Net Acreage |
245,805 |
321,563 |
918,535 |
3,023,386 |
4,509,289 | ||||||||||
Net Undeveloped Acreage |
146,096 |
161,607 |
285,692 |
3,010,908 |
3,604,303 | ||||||||||
PV-10: |
|||||||||||||||
Pre-Tax (millions)(4) |
$ |
183 |
$ |
163 |
$ |
1,325 |
$ |
(6) |
$ |
1,665 | |||||
PV of Taxes (millions)(4) |
– |
– |
– |
– |
– | ||||||||||
After-Tax (millions)(4) |
$ |
183 |
$ |
163 |
$ |
1,325 |
$ |
(6) |
$ |
1,665 | |||||
Percent of Total |
11% |
10% |
79% |
0% |
100% | ||||||||||
Percent Operated(5) |
95% |
100% |
99% |
100% |
98% | ||||||||||
(1) |
Other consists primarily of properties in Canada (which are subject to a moratorium), Colorado and Louisiana. |
(2) |
Total and Other capital investments excludes $26 million related to our E&P service companies. |
(3) |
Represents all producing wells, including wells in which we only have an overriding royalty interest, as of December 31, 2016. |
(4) |
Pre-tax PV-10 (a non-GAAP measure) is one measure of the value of a company's proved reserves that we believe is used by securities analysts to compare relative values among peer companies without regard to income taxes. The reconciling difference in pre-tax PV-10 and the after-tax PV-10, or standardized measure, is the discounted value of future income taxes on the estimated cash flows from our proved natural gas, oil and NGL reserves. |
(5) |
Based upon pre-tax PV-10 of proved developed producing activities. |
The Company's 2016 and three-year average proved developed finding and development costs were $0.75 and $1.00 per Mcfe, respectively, when excluding the impact of capitalizing interest and portions of G&A costs in accordance with the full cost method of accounting.
Proved developed finding and development costs – Proved developed (PDP) finding and development (F&D) costs are computed here by dividing exploration and development capital costs incurred, excluding capitalized interest and expenses, for the indicated period by PDP reserve additions and proved undeveloped (PUD) conversions for that same period. At times, adjustments are made to this calculation in order to improve usefulness for investors. For example, adjustments are made to exclude the differences between accounting methods to improve comparability. The following computes PDP F&D costs for the periods ending December 31, 2016, 2015 and 2014 and the three years ending December 31, 2016. A breakdown is also shown detailing these amounts separately for Northeast Appalachia, Southwest Appalachia and the Fayetteville Shale.
TOTAL COMPANY PDP F&D | |||||||||||
Three-Year | |||||||||||
12 Months Ended December 31, |
Average | ||||||||||
2016 |
2015 |
2014 |
2016 | ||||||||
Total PDP Adds (Bcfe): |
|||||||||||
New PDP adds |
257 |
416 |
531 |
1,204 | |||||||
PUD conversions |
220 |
1,044 |
790 |
2,054 | |||||||
Total PDP Adds |
477 |
1,460 |
1,321 |
3,258 | |||||||
Costs Incurred (in millions): |
|||||||||||
Proved property acquisition costs |
$ |
– |
$ |
81 |
$ |
1,455 |
$ |
1,536 | |||
Unproved property acquisition costs |
171 |
692 |
3,934 |
4,797 | |||||||
Exploration costs |
17 |
50 |
232 |
299 | |||||||
Development costs |
433 |
1,417 |
1,600 |
3,450 | |||||||
Capitalized Costs Incurred |
$ |
621 |
$ |
2,240 |
$ |
7,221 |
$ |
10,082 | |||
Subtract (in millions): |
|||||||||||
Proved property acquisition costs |
$ |
– |
$ |
(81) |
$ |
(1,455) |
$ |
(1,536) | |||
Unproved property acquisition costs |
(171) |
(692) |
(3,934) |
(4,797) | |||||||
Capitalized interest and expense(1) associated with development and exploration |
(91) |
(187) |
(206) |
(484) | |||||||
PDP Costs Incurred |
$ |
359 |
$ |
1,280 |
$ |
1,626 |
$ |
3,265 | |||
PDP F&D |
$ |
0.75 |
$ |
0.88 |
$ |
1.23 |
$ |
1.00 |
Note: Amounts may not add due to rounding | |
(1) |
Adjusting for the impacts of the full cost accounting method for comparability. |
DIVISION PDP F&D | ||||||||||||||
12 Months Ended December 31, 2016 | ||||||||||||||
Appalachia |
Fayetteville |
|||||||||||||
Northeast |
Southwest |
Shale |
Other |
Total | ||||||||||
Total PDP Adds (Bcfe): |
||||||||||||||
New PDP adds |
81 |
157 |
19 |
– |
257 | |||||||||
PUD conversions |
181 |
– |
39 |
– |
220 | |||||||||
Total PDP Adds |
262 |
157 |
58 |
– |
477 | |||||||||
Costs Incurred (in millions): |
||||||||||||||
Proved property acquisition costs |
$ |
– |
$ |
– |
$ |
– |
$ |
– |
$ |
– | ||||
Unproved property acquisition costs |
11 |
149 |
3 |
8 |
171 | |||||||||
Exploration costs |
8 |
8 |
1 |
– |
17 | |||||||||
Development costs |
178 |
133 |
86 |
36 |
433 | |||||||||
Capitalized Costs Incurred |
$ |
197 |
$ |
290 |
$ |
90 |
$ |
44 |
$ |
621 | ||||
Subtract (in millions): |
||||||||||||||
Proved property acquisition costs |
$ |
– |
$ |
– |
$ |
– |
$ |
– |
$ |
– | ||||
Unproved property acquisition costs |
(11) |
(149) |
(3) |
(8) |
(171) | |||||||||
Capitalized interest and expense(1) associated with development and exploration |
(31) |
(28) |
(21) |
(11) |
(91) | |||||||||
PDP Costs Incurred |
$ |
155 |
$ |
113 |
$ |
66 |
$ |
25 |
$ |
359 | ||||
PDP F&D |
$ |
0.59 |
$ |
0.72 |
$ |
1.14 |
$ |
– |
$ |
0.75 |
Note: Amounts may not add due to rounding | |
(1) |
Adjusting for the impacts of the full cost accounting method for comparability. |
The Company believes that providing a measure of PDP F&D costs is useful for investors as a means of evaluating a Company's cost to add proved reserves on a per thousand cubic feet of natural gas equivalent basis. These measures are provided in addition to, and not as an alternative for the financial statements, including the notes thereto, contained in Southwestern's Annual Report on Form 10-K. Due to various factors, including timing differences, PDP F&D costs do not necessarily reflect precisely the costs associated with particular reserves. Changes in commodity prices can affect the magnitude of recorded increases in reserves independent of the related costs of such increases. As a result of the foregoing factors and various factors that could materially affect the timing and amounts of future increases in reserves and the timing and amounts of future costs, including factors disclosed in Southwestern's filings with the SEC, future PDP F&D costs may differ materially from those set forth above. Further, the methods used by Southwestern to calculate its PDP F&D costs may differ significantly from methods used by other companies to compute similar measures and, as a result, Southwestern's PDP F&D costs may not be comparable to similar measures provided by other companies.
2016 Operational Review
During 2016, Southwestern invested a total of approximately $623 million in our E&P business, and participated in drilling 62 wells, completed 86 wells, placed 85 wells to sales and had 135 wells in progress. Of the 135 wells in progress at year-end, 73, 42 and 20 were located in our Northeast Appalachia, Southwest Appalachia and Fayetteville Shale operating areas, respectively, and 35 of these wells are waiting on pipeline or production facilities.
For the years ended December | |||||
2016 |
2015 | ||||
E&P Capital Investments by Type |
(in millions) | ||||
Exploratory and development drilling, including workovers |
$ |
358 |
$ |
1,226 | |
Acquisitions and leasehold |
23 |
607 | |||
Seismic expenditures |
1 |
6 | |||
Drilling rigs, sand facility and other |
2 |
40 | |||
Capitalized interest and expense |
239 |
379 | |||
Total E&P capital investments |
$ |
623 |
$ |
2,258 | |
E&P Capital Investments by Area |
|||||
Northeast Appalachia |
$ |
165 |
$ |
652 | |
Southwest Appalachia |
130 |
659 | |||
Fayetteville Shale |
65 |
496 | |||
New Ventures |
(2) |
48 | |||
E&P Services & Other |
26 |
24 | |||
Capitalized interest and expense |
239 |
379 | |||
Total E&P capital investments |
$ |
623 |
$ |
2,258 |
Year-end 2016 E&P Division Results |
||||||||
Appalachia |
Fayetteville | |||||||
Northeast |
Southwest |
Shale | ||||||
Production (Bcfe) |
350 |
148 |
375 | |||||
Gross operated production at year-end 2016 (Mmcfe/d) |
1,138 |
577 |
1,377 | |||||
Reserves: |
||||||||
Reserves (Bcfe) |
1,574 |
677 |
2,997 | |||||
Capital investments ($ in millions) |
||||||||
Exploratory and development drilling, including workovers |
$ |
160 |
$ |
111 |
$ |
63 | ||
Acquisition and leasehold |
3 |
18 |
2 | |||||
Seismic and other |
2 |
1 |
- | |||||
Capitalized interest and expense |
39 |
158 |
21 | |||||
Total capital investments |
$ |
204 |
$ |
288 |
$ |
86 | ||
Gross operated well count summary |
||||||||
Drilled |
37 |
15 |
10 | |||||
Completed |
33 |
17 |
36 | |||||
Wells to sales |
24 |
18 |
43 | |||||
Wells in progress |
73 |
42 |
20 | |||||
Year-end drilled uncompleted wells |
46 |
40 |
13 | |||||
Realized price |
||||||||
NYMEX Henry Hub price ($/MMBtu) |
$ |
2.46 |
$ |
2.46 |
$ |
2.46 | ||
Discount to NYMEX ($/Mcf) |
$ |
(1.12) |
$ |
(0.75) |
$ |
(0.66) | ||
Average realized gas price, excluding hedges ($/Mcf) |
$ |
1.34 |
$ |
1.71 |
$ |
1.80 |
Northeast Appalachia – In the fourth quarter of 2016, the Company placed 12 wells to sales that had an average lateral length of 6,075 feet and an average cost of $4.7 million per well. The average rate for the first 30 days for wells online was 17,178 Mcf per day in the fourth quarter of 2016 compared to 4,796 Mcf per day in the fourth quarter of 2015. The stronger early rates are a result of increased completion intensity and optimized flow techniques implemented during the second half of the year. During the fourth quarter, Northeast Appalachia placed 11 wells to sales that were completed using increased completion intensity and optimized flow techniques, with all wells exhibiting encouraging early results. One example is the Cramer pad in Susquehanna County, where the Company brought five wells to sales in the fourth quarter with a cumulative rate of approximately 92 million cubic feet per day. Additionally, the Racine pad that was placed online in the third quarter of 2016 has continued to outperform offset wells, producing 75% more volumes in the first 125 days. While the Company continues to assess what portion of these increased volumes relate to incremental expected recovery and what portion relates to acceleration, these results clearly indicate additional value is being created with these new methods.
Additionally, the Company continued its delineation efforts in Tioga County, where initial infrastructure was installed, and it placed its first two well to sales in January 2017. The well results observed to date confirm the productivity of the acreage and the Company intends to further develop this area throughout 2017.
In 2016, Southwestern's operated horizontal wells had an average completed well cost of $5.3 million per well and an average horizontal lateral length of 6,142 feet. This compares to an average completed operated well cost of $5.4 million per well and an average horizontal lateral length of 5,403 feet in 2015.
As of December 31, 2016, Southwestern had spud or acquired 568 operated wells, of which 447 were horizontal and on production and 73 were in progress. Of the 447 operated horizontal wells on production, 281 were located in Susquehanna County, 140 were located in Bradford County, 25 were located in Lycoming County, and one was located in Wyoming County. Of the 73 wells in progress, 46 were either waiting on completion or waiting to be placed to sales, including 36 in Susquehanna County, six in Bradford County and four wells in Sullivan, Tioga and Wyoming Counties, combined.
Southwest Appalachia – In the fourth quarter of 2016, Southwestern brought online seven wells in Southwest Appalachia, including the Company's first drilled and completed Utica well, the O.E. Burge 501H. It was completed with a lateral length of 8,061 feet and is exhibiting the vast potential of this reservoir in the Company's Southwest Appalachia acreage. With the encouraging results, the Company accelerated the timeline for drilling its next Utica test well, which began drilling earlier this month.
Additionally, completion intensity testing continued during the quarter with increased amounts of proppant being used in some wells. In one group of wells, the Company tested one well using approximately 5,000 pounds per lateral foot of proppant and four wells using approximately 3,500 pounds per lateral foot, compared to the recent standard of 2,000 pounds per lateral foot. These wells, along with other test wells, have recently been placed online and early results are expected to be available at the end of the first quarter.
In 2016, of the 18 wells brought to sales, 15 were drilled and completed by Southwestern, of which 14 targeted the Marcellus Shale. The Marcellus wells had an average completed well cost of $5.4 million per well and an average horizontal lateral length of 5,316 feet. This compares to an average completed operated well cost of $6.9 million per well and an average horizontal lateral length of 6,985 feet in 2015.
The Company had a total of 299 horizontal and four vertical wells that the Company operated and that were on production as of December 31, 2016. Additionally, there were 42 horizontal wells in progress at the end of 2016, of which 20 were waiting on pipeline or production facilities.
Fayetteville Shale – During the fourth quarter of 2016, the Company placed 22 wells to sales with an average completed well cost of $2.8 million per well, and average horizontal lateral length of 5,547 feet. Of the 22 wells placed to sales, four were completed using increased proppant and tighter stage spacing. These new completion methods indicate improved initial well productivity and the Company will continue to evaluate additional results to optimize economic value.
During the fourth quarter of 2016, we continued delineation activity in the Moorefield, located just beneath the Fayetteville Shale. Eight Moorefield wells were drilled during the quarter, with seven of these being completed in the first quarter of 2017. These wells are expected to be placed to sales in March.
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three and twelve months ended December 31, 2016 and December 31, 2015, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net loss attributable to common stock |
$ |
(237) |
$ |
(2,134) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
(6) |
– | |||
Impairment of natural gas and oil properties |
– |
2,576 | |||
Restructuring and other one-time charges |
12 |
– | |||
Gain on sale of assets, net |
– |
(7) | |||
Transaction costs |
– |
1 | |||
Loss on certain derivatives |
324 |
50 | |||
Adjustments due to inventory valuation |
– |
32 | |||
Adjustments due to discrete tax items(1) |
74 |
483 | |||
Tax impact on adjustments |
(128) |
(1,007) | |||
Adjusted net income (loss) attributable to common stock |
$ |
39 |
$ |
(6) |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments in the fourth quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended December 31, | |||||
2016 |
2015 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted loss per share |
$ |
(0.48) |
$ |
(5.58) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
(0.01) |
– | |||
Impairment of natural gas and oil properties |
– |
6.74 | |||
Restructuring and other one-time charges |
0.02 |
– | |||
Gain on sale of assets, net |
– |
(0.02) | |||
Transaction costs |
– |
0.00 | |||
Loss on certain derivatives |
0.66 |
0.13 | |||
Adjustments due to inventory valuation |
– |
0.08 | |||
Adjustments due to discrete tax items(1) |
0.15 |
1.26 | |||
Tax impact on adjustments |
(0.26) |
(2.63) | |||
Adjusted diluted earnings (loss) per share |
$ |
0.08 |
$ |
(0.02) |
(1) |
Primarily relates to the exclusion of certain discrete tax adjustments in the fourth quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
12 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net loss attributable to common stock |
$ |
(2,751) |
$ |
(4,662) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
– |
(13) | |||
Impairment of natural gas and oil properties |
2,321 |
6,950 | |||
Restructuring and other one-time charges |
89 |
2 | |||
Gain on sale of assets, net |
(3) |
(283) | |||
Loss on early extinguishment of debt and other(1) |
57 |
– | |||
Transaction costs |
– |
54 | |||
Loss on certain derivatives |
373 |
155 | |||
Adjustments due to inventory valuation |
3 |
32 | |||
Adjustments due to discrete tax items(2) |
978 |
483 | |||
Tax impact on adjustments |
(1,074) |
(2,647) | |||
Adjusted net income (loss) attributable to common stock |
$ |
(7) |
$ |
71 |
(1) |
Includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
12 Months Ended December 31, | |||||
2016 |
2015 | ||||
Diluted earnings (loss) per share: |
|||||
Diluted loss per share |
$ |
(6.32) |
$ |
(12.25) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
– |
(0.03) | |||
Impairment of natural gas and oil properties |
5.33 |
18.26 | |||
Restructuring and other one-time charges |
0.20 |
0.01 | |||
Gain on sale of assets, net |
(0.00) |
(0.74) | |||
Loss on early extinguishment of debt and other(1) |
0.13 |
– | |||
Transaction costs |
– |
0.14 | |||
Loss on certain derivatives |
0.86 |
0.41 | |||
Adjustments due to inventory valuation |
0.01 |
0.08 | |||
Adjustments due to discrete tax items(2) |
2.25 |
1.27 | |||
Tax impact on adjustments |
(2.47) |
(6.96) | |||
Adjusted diluted earnings (loss) per share |
$ |
(0.01) |
$ |
0.19 |
(1) |
Includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
Primarily relates to the exclusion of certain discrete tax adjustments due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2017 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
161 |
$ |
353 | |
Add back: |
|||||
Changes in operating assets and liabilities |
49 |
(47) | |||
Restructuring charges |
1 |
– | |||
Net cash flow |
$ |
211 |
$ |
306 | |
12 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
498 |
$ |
1,580 | |
Add back: |
|||||
Changes in operating assets and liabilities |
99 |
(112) | |||
Restructuring charges |
48 |
– | |||
Net cash flow |
$ |
645 |
$ |
1,468 | |
3 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating income (loss) |
$ |
122 |
$ |
(2,561) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
2,576 | |||
Gain on sale of assets, net |
– |
(7) | |||
Restructuring and other one-time charges |
12 |
– | |||
Adjusted operating income |
$ |
134 |
$ |
8 | |
12 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Operating income (loss): |
|||||
Operating loss |
$ |
(2,195) |
$ |
(6,522) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
2,321 |
6,950 | |||
Gain on sale of assets, net |
– |
(283) | |||
Restructuring and other one-time charges |
89 |
1 | |||
Adjusted operating income |
$ |
215 |
$ |
146 | |
3 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
82 |
$ |
(2,633) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
– |
2,576 | |||
Gain on sale of assets, net |
– |
(7) | |||
Restructuring and other one-time charges |
12 |
– | |||
Adjusted E&P segment operating income (loss) |
$ |
94 |
$ |
(64) | |
12 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating loss |
$ |
(2,404) |
$ |
(7,104) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
2,321 |
6,950 | |||
Gain on sale of assets, net |
– |
(6) | |||
Restructuring and other one-time charges |
86 |
1 | |||
Adjusted E&P segment operating income (loss) |
$ |
3 |
$ |
(159) | |
12 Months Ended December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Midstream segment operating income: |
|||||
Midstream segment operating income |
$ |
209 |
$ |
583 | |
Add back: |
|||||
Restructuring charges |
3 |
– | |||
Gain on sale of assets, net |
– |
(277) | |||
Adjusted Midstream segment operating income |
$ |
212 |
$ |
306 | |
December 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
4,653 |
$ |
4,705 | |
Subtract: |
|||||
Cash and cash equivalents |
(1,423) |
(15) | |||
Net debt |
$ |
3,230 |
$ |
4,690 |
Southwestern management will host a teleconference call on Friday, February 24, 2016 at 10:00 a.m. Eastern to discuss its fourth quarter and year-end 2016 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
OPERATING STATISTICS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months |
For the years ended | |||||||||||
December 31, |
December 31, | |||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
Exploration & Production |
||||||||||||
Production |
||||||||||||
Gas production (Bcf) |
183 |
226 |
788 |
899 | ||||||||
Oil production (MBbls) |
463 |
569 |
2,192 |
2,265 | ||||||||
NGL production (MBbls) |
2,792 |
3,328 |
12,372 |
10,702 | ||||||||
Total production (Bcfe) |
202 |
249 |
875 |
976 | ||||||||
Commodity Prices |
||||||||||||
Average realized gas price per Mcf, including derivatives |
$ |
2.07 |
$ |
2.07 |
$ |
1.64 |
$ |
2.37 | ||||
Average realized gas price per Mcf, excluding derivatives |
$ |
2.00 |
$ |
1.48 |
$ |
1.59 |
$ |
1.91 | ||||
Average realized oil price per Bbl |
$ |
41.18 |
$ |
27.36 |
$ |
31.20 |
$ |
33.25 | ||||
Average realized NGL price per Bbl |
$ |
12.08 |
$ |
7.62 |
$ |
7.46 |
$ |
6.80 | ||||
Summary of Derivative Activity in the Statement of Operations |
||||||||||||
Settled commodity amounts included in "Operating Revenues" (in millions) |
$ |
– |
$ |
64 |
$ |
– |
$ |
209 | ||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
14 |
$ |
69 |
$ |
36 |
$ |
206 | ||||
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(330) |
$ |
(50) |
$ |
(375) |
$ |
(153) | ||||
Average unit costs per Mcfe |
||||||||||||
Lease operating expenses |
$ |
0.87 |
$ |
0.91 |
$ |
0.87 |
$ |
0.92 | ||||
General & administrative expenses (1) |
$ |
0.27 |
$ |
0.20 |
$ |
0.22 |
$ |
0.21 | ||||
Taxes, other than income taxes (2) |
$ |
0.11 |
$ |
0.09 |
$ |
0.10 |
$ |
0.10 | ||||
Full cost pool amortization |
$ |
0.30 |
$ |
0.78 |
$ |
0.38 |
$ |
1.00 | ||||
Midstream |
||||||||||||
Volumes marketed (Bcfe) |
248 |
290 |
1,062 |
1,127 | ||||||||
Volumes gathered (Bcf) |
138 |
179 |
601 |
799 |
(1) |
Excludes $12 million and $83 million of restructuring and other one-time charges for the three months and year ended December 31, 2016, respectively. |
(2) |
Excludes $3 million of restructuring charges for the year ended December 31, 2016. |
STATEMENTS OF OPERATIONS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the years ended | |||||||||||
December 31, |
December 31, | |||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
(in millions, except share/per share amounts) | ||||||||||||
Operating Revenues |
||||||||||||
Gas sales |
$ |
367 |
$ |
406 |
$ |
1,273 |
$ |
1,946 | ||||
Oil sales |
19 |
16 |
69 |
76 | ||||||||
NGL sales |
33 |
26 |
92 |
73 | ||||||||
Marketing |
233 |
200 |
864 |
863 | ||||||||
Gas gathering |
32 |
39 |
138 |
175 | ||||||||
684 |
687 |
2,436 |
3,133 | |||||||||
Operating Costs and Expenses |
||||||||||||
Marketing purchases |
237 |
198 |
864 |
852 | ||||||||
Operating expenses |
137 |
182 |
592 |
689 | ||||||||
General and administrative expenses |
76 |
58 |
247 |
246 | ||||||||
Restructuring charges |
1 |
– |
78 |
– | ||||||||
Depreciation, depletion and amortization |
87 |
215 |
436 |
1,091 | ||||||||
Impairment of natural gas and oil properties |
– |
2,576 |
2,321 |
6,950 | ||||||||
Gain on sale of assets, net |
– |
(7) |
– |
(283) | ||||||||
Taxes, other than income taxes |
24 |
26 |
93 |
110 | ||||||||
562 |
3,248 |
4,631 |
9,655 | |||||||||
Operating Income (Loss) |
122 |
(2,561) |
(2,195) |
(6,522) | ||||||||
Interest Expense |
||||||||||||
Interest on debt |
58 |
47 |
226 |
200 | ||||||||
Other interest charges |
2 |
6 |
14 |
60 | ||||||||
Interest capitalized |
(29) |
(49) |
(152) |
(204) | ||||||||
31 |
4 |
88 |
56 | |||||||||
Gain (Loss) on Derivatives |
(311) |
17 |
(339) |
47 | ||||||||
Loss on Early Extinguishment of Debt |
– |
– |
(51) |
– | ||||||||
Other Income (Loss), Net |
1 |
(32) |
1 |
(30) | ||||||||
Loss Before Income Taxes |
(219) |
(2,580) |
(2,672) |
(6,561) | ||||||||
Income Tax benefit |
||||||||||||
Current |
(7) |
(9) |
(7) |
(2) | ||||||||
Deferred |
(2) |
(464) |
(22) |
(2,003) | ||||||||
(9) |
(473) |
(29) |
(2,005) | |||||||||
Net Loss |
(210) |
(2,107) |
(2,643) |
(4,556) | ||||||||
Mandatory convertible preferred stock dividend |
27 |
27 |
108 |
106 | ||||||||
Net Loss Attributable to Common Stock |
$ |
(237) |
$ |
(2,134) |
$ |
(2,751) |
$ |
(4,662) | ||||
Loss Per Common Share |
||||||||||||
Basic |
$ |
(0.48) |
$ |
(5.58) |
$ |
(6.32) |
$ |
(12.25) | ||||
Diluted |
$ |
(0.48) |
$ |
(5.58) |
$ |
(6.32) |
$ |
(12.25) | ||||
Weighted Average Common Shares Outstanding | ||||||||||||
Basic |
489,287,827 |
382,334,978 |
435,337,402 |
380,521,039 | ||||||||
Diluted |
489,287,827 |
382,334,978 |
435,337,402 |
380,521,039 |
BALANCE SHEETS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
December 31, |
December 31, | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,872 |
$ |
393 | ||
Property and equipment |
24,489 |
24,364 | ||||
Less: Accumulated depreciation, depletion and amortization |
(19,534) |
(16,821) | ||||
Total property and equipment, net |
4,955 |
7,543 | ||||
Other long-term assets |
249 |
150 | ||||
Total assets |
7,076 |
8,086 | ||||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
1,064 |
707 | ||||
Long-term debt |
4,612 |
4,704 | ||||
Pension and other postretirement liabilities |
49 |
50 | ||||
Other long-term liabilities |
434 |
343 | ||||
Total liabilities |
6,159 |
5,804 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 495,248,369 shares as of December 31, 2016 (does not include 2,751,410 shares issued on January 17, 2017 on account of a dividend declared on December 12, 2016) and 390,138,549 as of December 31, 2015 |
5 |
4 | ||||
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of December 31, 2016 and 2015, conversion in January 2018 |
– |
– | ||||
Additional paid-in capital |
4,677 |
3,409 | ||||
Accumulated deficit |
(3,725) |
(1,082) | ||||
Accumulated other comprehensive loss |
(39) |
(48) | ||||
Common stock in treasury; 31,269 shares as of December 31, 2016 and 47,149 as of December 31, 2015, respectively |
(1) |
(1) | ||||
Total equity |
917 |
2,282 | ||||
Total liabilities and equity |
$ |
7,076 |
$ |
8,086 |
STATEMENTS OF CASH FLOWS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
For the years ended | ||||||
December 31, | ||||||
2016 |
2015 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities: |
||||||
Net loss |
$ |
(2,643) |
$ |
(4,556) | ||
Adjustments to reconcile net loss to net cash provided by operating activities: |
||||||
Depreciation, depletion and amortization |
436 |
1,092 | ||||
Impairment of natural gas and oil properties |
2,321 |
6,950 | ||||
Amortization of debt issuance costs |
14 |
53 | ||||
Deferred income taxes |
(22) |
(2,003) | ||||
Loss on derivatives, net of settlement |
373 |
155 | ||||
Stock-based compensation |
29 |
26 | ||||
Gain on sales of assets, net |
– |
(283) | ||||
Restructuring charges |
30 |
– | ||||
Loss on early extinguishment of debt |
51 |
– | ||||
Other |
8 |
34 | ||||
Change in assets and liabilities |
(99) |
112 | ||||
Net cash provided by operating activities |
498 |
1,580 | ||||
Cash Flows From Investing Activities: |
||||||
Capital investments |
(593) |
(1,798) | ||||
Acquisitions |
– |
(579) | ||||
Proceeds from sale of property and equipment |
430 |
729 | ||||
Other |
1 |
10 | ||||
Net cash used in investing activities |
(162) |
(1,638) | ||||
Cash Flows From Financing Activities: |
||||||
Payments on current portion of long-term debt |
(1) |
(1) | ||||
Payments on long-term debt |
(1,175) |
(500) | ||||
Payments on short-term debt |
– |
(4,500) | ||||
Payments on revolving credit facility |
(3,268) |
(3,024) | ||||
Borrowings under revolving credit facility |
3,152 |
2,840 | ||||
Payments on commercial paper |
(242) |
(7,988) | ||||
Borrowings under commercial paper |
242 |
7,988 | ||||
Change in bank drafts outstanding |
(20) |
12 | ||||
Proceeds from issuance of long-term debt |
1,191 |
2,950 | ||||
Debt issuance costs |
(17) |
(20) | ||||
Proceeds from issuance of common stock |
1,247 |
669 | ||||
Proceeds from issuance of mandatory convertible preferred stock |
– |
1,673 | ||||
Preferred stock dividend |
(27) |
(79) | ||||
Cash paid for tax withholding |
(9) |
– | ||||
Other |
(1) |
– | ||||
Net cash provided by financing activities |
1,072 |
20 | ||||
Increase (decrease) in cash and cash equivalents |
1,408 |
(38) | ||||
Cash and cash equivalents at beginning of year |
15 |
53 | ||||
Cash and cash equivalents at end of year |
$ |
1,423 |
$ |
15 |
SEGMENT INFORMATION (Unaudited) |
|||||||||||||||
Southwestern Energy Company and Subsidiaries |
Exploration |
||||||||||||||
and |
Midstream |
||||||||||||||
Production |
Services |
Other |
Eliminations |
Total | |||||||||||
(in millions) | |||||||||||||||
Three months ended December 31, 2016 |
|||||||||||||||
Revenues |
$ |
415 |
$ |
707 |
$ |
– |
$ |
(438) |
$ |
684 | |||||
Marketing purchases |
– |
612 |
– |
(375) |
237 | ||||||||||
Operating expenses |
175 |
25 |
– |
(63) |
137 | ||||||||||
General and administrative expenses |
63 |
13 |
– |
– |
76 | ||||||||||
Restructuring charges |
1 |
– |
– |
– |
1 | ||||||||||
Depreciation, depletion and amortization |
71 |
16 |
– |
– |
87 | ||||||||||
Taxes, other than income taxes |
23 |
1 |
– |
– |
24 | ||||||||||
Operating income |
82 |
40 |
– |
– |
122 | ||||||||||
Capital investments (1) |
251 |
18 |
3 |
– |
272 | ||||||||||
Three months ended December 31, 2015 |
|||||||||||||||
Revenues |
$ |
441 |
$ |
668 |
$ |
(1) |
$ |
(421) |
$ |
687 | |||||
Marketing purchases |
– |
541 |
– |
(343) |
198 | ||||||||||
Operating expenses |
229 |
33 |
(2) |
(78) |
182 | ||||||||||
General and administrative expenses |
49 |
9 |
– |
– |
58 | ||||||||||
Depreciation, depletion and amortization |
204 |
10 |
1 |
– |
215 | ||||||||||
Impairment of natural gas and oil properties |
2,576 |
– |
– |
– |
2,576 | ||||||||||
Gain on sale of assets, net |
(7) |
– |
– |
– |
(7) | ||||||||||
Taxes, other than income taxes |
23 |
3 |
– |
– |
26 | ||||||||||
Operating income (loss) |
(2,633) |
72 |
– |
– |
(2,561) | ||||||||||
Capital investments (1) |
378 |
3 |
2 |
– |
383 | ||||||||||
Year ended December 31, 2016 |
|||||||||||||||
Revenues |
$ |
1,413 |
$ |
2,569 |
$ |
– |
$ |
(1,546) |
$ |
2,436 | |||||
Marketing purchases |
– |
2,145 |
– |
(1,281) |
864 | ||||||||||
Operating expenses |
761 |
96 |
– |
(265) |
592 | ||||||||||
General and administrative expenses |
204 |
43 |
– |
– |
247 | ||||||||||
Restructuring charges |
75 |
3 |
– |
– |
78 | ||||||||||
Depreciation, depletion and amortization |
371 |
65 |
– |
– |
436 | ||||||||||
Impairment of natural gas and oil properties |
2,321 |
– |
– |
– |
2,321 | ||||||||||
Taxes, other than income taxes |
85 |
8 |
– |
– |
93 | ||||||||||
Operating income (loss) |
(2,404) |
209 |
– |
– |
(2,195) | ||||||||||
Capital investments (1) |
623 |
21 |
4 |
– |
648 | ||||||||||
Year ended December 31, 2015 |
|||||||||||||||
Revenues |
$ |
2,074 |
$ |
3,119 |
$ |
– |
$ |
(2,060) |
$ |
3,133 | |||||
Marketing purchases |
– |
2,566 |
– |
(1,714) |
852 | ||||||||||
Operating expenses |
899 |
136 |
– |
(346) |
689 | ||||||||||
General and administrative expenses |
207 |
39 |
– |
– |
246 | ||||||||||
Depreciation, depletion and amortization |
1,028 |
62 |
1 |
– |
1,091 | ||||||||||
Impairment of natural gas and oil properties |
6,950 |
– |
– |
– |
6,950 | ||||||||||
Gain on sale of assets, net |
(6) |
(277) |
– |
– |
(283) | ||||||||||
Taxes, other than income taxes |
100 |
10 |
– |
– |
110 | ||||||||||
Operating income (loss) |
(7,104) |
583 |
(1) |
– |
(6,522) | ||||||||||
Capital investments (1) |
2,258 |
167 |
12 |
– |
2,437 |
(1) |
Capital investments includes an increase of $67 million and a decrease of $28 million for the three months ended December 31, 2016 and 2015, respectively, and an increase of $43 million and a decrease of $33 million for the years ended December 31, 2016 and 2015, respectively, relating to the change in accrued expenditures between periods. |
SOURCE Southwestern Energy Company
HOUSTON, Feb. 23, 2017 Southwestern Energy Company (NYSE: SWN) today announced its total capital investment program in 2017 is planned to be approximately $1.175 to $1.275 billion, funded by expected cash flow and $200 million remaining from its 2016 equity raise. With this investment, Southwestern is targeting total net gas and liquids production of 890 to 910 Bcfe in 2017, an increase over the company's 2016 production of 875 Bcfe and an increase of approximately 20% when comparing 2017 exit production rates to 2016 exit production rates. As part of this plan, the Company's Appalachian area annual production volumes are expected to grow approximately 17% (using midpoints) over 2016 and approximately 40% based on exit production rates. Assuming a capital budget based on current strip pricing in both 2017 and 2018, the Company anticipates delivering double-digit production growth in 2018.
"We are attacking 2017 with even more vigor and commitment than ever before," remarked Bill Way, President and Chief Executive Officer of Southwestern Energy. "With capital discipline as a foundation, we are able to capitalize on the improved commodity price environment and return to value-added growth in 2017 and beyond. We have many new ideas we are testing, allowing us to further improve on our operational excellence from our premier portfolio of assets and transportation capacity."
As we navigate the current commodity market turbulence, we will leverage our improving financial strength, capital efficiency and operational excellence while focusing on economic value creation. Details on these initiatives, and the expected results associated with this plan, are described below.
The following tables provide detailed information and guidance for 2017 based on an average natural gas price of $3.25 per Mcf and an average oil price of $55.00 per barrel.
2017 Guidance | |
in millions (except per share amounts, production and well count) |
$3.25 / $55.00 |
Capital investments: |
|
Discretionary capital |
$750 - $830 |
Capitalized interest and expenses |
$225 - $245 |
Subtotal capital investments |
$975 - $1,075 |
Capital earmarked from July 2016 equity offering |
$200 |
Total capital investments |
$1,175 - $1,275 |
Net cash flow (1) |
$1,075 - $1,125 |
Net income (2) |
$308 - $368 |
Net income attributable to preferred stock (2) |
$25 - $35 |
Mandatory convertible preferred stock dividend |
$108 |
Net income attributable to common stock (2) |
$175 - $225 |
Diluted earnings per common share |
$0.35 - $0.45 |
Adjusted EBITDA (1) |
$1,175 - $1,225 |
Production (Bcfe) |
890 – 910 |
Wells drilled |
110 – 130 |
Wells completed |
140 – 160 |
Wells placed to sales |
150 – 170 |
Ending DUC inventory |
55 – 65 |
(1) |
This represents a Non-GAAP measure; see "Explanation and Reconciliation of Non-GAAP Financial Measures" below. |
(2) |
Assumes 38% income tax rate and no unsettled derivative gain/losses. |
Estimated Production and Capital Investments in 2017
2017 Guidance | ||||
Production |
Capital | |||
(Bcfe) |
($ in millions) | |||
Northeast Appalachia |
400 – 408 |
$ |
405 – 425 | |
Southwest Appalachia |
174 – 180 |
400 – 420 | ||
Fayetteville Shale |
315 – 320 |
105 – 120 | ||
Midstream Services |
15 – 20 | |||
New Ventures & other E&P |
1 – 2 |
15 – 25 | ||
Corporate |
10 – 20 | |||
Capitalized interest |
115 – 125 | |||
Capitalized expense |
110 – 120 | |||
Total |
890 - 910 |
$ |
1,175 - 1,275 |
Estimated Production by Quarter in 2017
1st Quarter |
2nd Quarter |
3rd Quarter |
4th Quarter |
Total Year | |||||
Guidance: |
|||||||||
Natural Gas (Bcf) |
183 – 186 |
199 – 203 |
206 – 210 |
210 – 215 |
798 – 814 | ||||
Oil (MBbls) |
455 – 505 |
525 – 575 |
730 – 780 |
760 – 810 |
2,470 – 2,670 | ||||
NGLs (MBbls) |
2,850 – 2,950 |
3,050 – 3,150 |
3,510 – 3,610 |
3,550 – 3,650 |
12,960 – 13,360 | ||||
Total Production (Bcfe) |
203 – 207 |
220 - 225 |
231 - 236 |
236 - 242 |
890 – 910 |
Estimated E&P Pricing Deductions in 2017 |
|
Avg gas discount to NYMEX including transportation(1) |
$0.80 - $0.96 per Mcf |
Avg oil discount to WTI including transportation |
$8.00 - $10.00 per Bbl |
Avg NGL realization including transportation |
20% - 25% of WTI |
Estimated E&P Operating Expenses in 2017 (per Mcfe) |
|
Lease operating expenses |
$0.89 - $0.94 |
General & administrative expense |
$0.20 - $0.24 |
Taxes, other than income taxes |
$0.09 - $0.11 |
Other Items in 2017 |
|
Midstream EBITDA ($ in millions) |
$210 - $225 |
Interest expense - net of capitalization ($ in millions) |
$125 - $135 |
Income tax rate (~100% Deferred)(2) |
38.0% |
(1) |
Excludes impact of financial basis hedges |
(2) |
Assumes no impact from valuation allowance |
Operational Update
During 2017, the Company plans to invest $1.1 billion to $1.2 billion in its E&P business, which includes $810 million to $860 million for drilling and completion activities, $220 million to $240 million for capitalized interest and expenses and $115 million to $130 million for land, seismic and other items. This program includes drilling 110 to 130 wells, to completing 140 to 160 wells and placing 150 to 170 wells to sales. In Southwest Appalachia, the Company plans to primarily focus its activity in the rich gas window of the play while further testing its Utica acreage with two additional wells. For the Marcellus wells, the Company expects the average 2017 completed well cost to be $6.6 million per well with approximately 7,400 foot average horizontal lateral length. In Northeast Appalachia, the 2017 program plans to primarily focus on its core area in Susquehanna County while further delineating its Tioga County acreage. For the Northeast Appalachia wells, the Company expects the average 2017 completed well cost to be $6.3 million per well with approximately 7,200 foot average horizontal lateral length. In Fayetteville, the Company plans to complete 14 to 16 Moorefield wells with an expected average completed well cost of $4.9 million for an average lateral length of approximately 7,900 feet and 15 to 17 Fayetteville Shale wells with an expected average completed well cost of $3.9 million for an average lateral length of approximately 6,600 feet. A summary of each area's gross well counts is provided in the table below.
Beginning |
Drilled |
Completed |
To Sales |
Ending DUC | ||||||
NE Appalachia |
46 |
52 - 60 |
61 - 69 |
67 - 75 |
28 - 33 | |||||
SW Appalachia |
40 |
42 - 50 |
50 - 58 |
52 - 60 |
27 - 32 | |||||
Fayetteville |
13 |
16 - 20 |
29 - 33 |
31 - 35 |
- | |||||
Total Well Count |
99 |
110 - 130 |
140 - 160 |
150 - 170 |
55 - 65 |
Hedging Update
As of February 21, 2017, the Company had approximately 560 Bcf of its 2017 forecasted gas production protected at an average swap or purchased put strike price of $3.02 per Mcf. Including the protected volumes, the Company retained upside exposure on approximately half of its forecasted 2017 volumes. Additionally, the Company had approximately 272 Bcf of its 2018 forecasted gas production protected at an average swap or purchased put strike price of $2.97 per Mcf, with upside exposure on approximately 82%, or 222 Bcf, of those protected volumes to $3.38 per Mcf. The Company also had approximately 80 Bcf of its 2019 forecasted gas production protected at an average purchased put strike price of $2.93 with upside exposure to $3.34 per Mcf.
A detailed breakdown of the Company's natural gas derivative financial instruments as of February 21, 2017 is shown below. Please refer to our annual report on Form 10-K 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 Puts |
Purchased |
Sold Calls | |||||||||
Financial protection on production |
|||||||||||||
2017(1) |
|||||||||||||
Fixed price swaps |
322 |
$ |
3.07 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
103 |
– |
– |
2.94 |
3.38 | ||||||||
Three-way costless collars |
135 |
– |
2.29 |
2.97 |
3.30 | ||||||||
Total |
560 |
||||||||||||
2018 |
|||||||||||||
Fixed price swaps |
50 |
$ |
3.02 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless collars |
14 |
– |
– |
3.00 |
3.46 | ||||||||
Three-way costless collars |
208 |
– |
2.37 |
2.96 |
3.37 | ||||||||
Total |
272 |
||||||||||||
2019 |
|||||||||||||
Three-way costless collars |
80 |
$ |
– |
$ |
2.50 |
$ |
2.93 |
$ |
3.34 | ||||
Total |
80 |
||||||||||||
Sold call options |
|||||||||||||
2017 |
86 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.25 | ||||
2018 |
63 |
– |
– |
– |
3.50 | ||||||||
2019 |
52 |
– |
– |
– |
3.50 | ||||||||
2020 |
32 |
– |
– |
– |
3.75 | ||||||||
Total |
233 |
Note: Amounts may not sum due to rounding |
(1) Includes positions settled since January 1, 2017 |
As of February 21, 2017, the Company had also taken steps to mitigate the volatility of basis differentials by protecting basis on approximately 303 Bcf of its 2017 forecasted natural gas production at a basis differential to NYMEX natural gas prices of approximately ($0.60) per Mcf, which includes the impact of both physical and financial basis hedges. A detailed breakdown of the Company's financial basis positions as of February 21, 2017 is shown below:
Financial basis positions (excludes physical positions) |
Dominion South |
TETCO M3 |
Total | ||||||
Volume |
Basis Diff |
Volume |
Basis Diff |
Volume |
Basis Diff | ||||
2017(1) |
95 |
($1.11) |
58 |
($0.54) |
153 |
($0.89) | |||
2018 |
18 |
($1.19) |
2 |
$0.79 |
20 |
($0.95) |
(1) Includes positions settled since January 1, 2017 |
Below is a summary of the approximate impacts of potential commodity price movements on expected net cash flow based on production estimates and the Company's hedging activities.
Price Sensitivities (based on annual prices) |
Net Cash Flow |
(in millions) | |
NYMEX Natural Gas: |
|
$2.75/$55.00 |
$900 - $950 |
$3.00/$55.00 |
$975 - $1,025 |
$3.25/$55.00 |
$1,075 - $1,125 |
$3.50/$55.00 |
$1,155 - $1,205 |
$3.75/$55.00 |
$1,195 - $1,245 |
$3.25/$65.00 |
$1,130 - $1,180 |
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 and 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 referenced in this news release are adjusted net income and adjusted EBITDA. Management presents these measures because (i) they are consistent with the manner in which the Company's performance is measured relative to the performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations below of GAAP financial measures to non-GAAP financial measures for the forecasted 2017 annual period. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
2017 Guidance | ||
NYMEX Price Assumption | ||
$3.25 Gas / $55.00 Oil | ||
(in millions) | ||
Cash flow from operating activities: |
||
Net cash provided by operating activities |
$1,075 - $1,125 | |
Add back (deduct): |
||
Change in operating assets and liabilities |
- | |
Net cash flow |
$1,075 - $1,125 |
Consolidated Adjusted EBITDA |
2017 Guidance | |
NYMEX Price Assumption | ||
$3.25 Gas / $55.00 Oil | ||
(in millions) | ||
Adjusted net income attributable to common stock |
$175 - $225 | |
Add back: |
||
Mandatory convertible preferred stock dividend |
108 - 108 | |
Participating securities – mandatory convertible preferred stock |
25 - 35 | |
Net income attributable to SWN |
$308 - $368 | |
Add back: |
||
Provision for income taxes |
191 – 229 | |
Interest expense |
125 – 135 | |
Non-cash stock based compensation |
20 – 30 | |
Depreciation, depletion and amortization |
495 – 515 | |
Adjusted EBITDA(1) |
$1,175 - $1,225 |
(1) Calculated consistently with provisions of the Company's principal credit agreements. |
Midstream Adjusted EBITDA |
2017 Guidance | |
NYMEX Price Assumption | ||
$3.25 Gas / $55.00 Oil | ||
(in millions) | ||
Adjusted net income attributable to common stock |
$85 - $105 | |
Add back: |
||
Mandatory convertible preferred stock dividend |
- | |
Participating securities – mandatory convertible preferred stock |
- | |
Net income attributable to SWN |
$85 - $105 | |
Add back: |
||
Provision for income taxes |
52 – 64 | |
Interest expense |
2 – 5 | |
Non-cash stock based compensation |
2 – 5 | |
Depreciation, depletion and amortization |
58 - 64 | |
Adjusted EBITDA |
$210 - $225 |
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; 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; unexpected increases in service or other costs related to drilling and completion activities; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, Feb. 13, 2017 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2016 Fourth Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, February 24, 2017, at 10:00 a.m. EST with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Fourth Quarter 2016 Earnings |
When: |
February 24, 2017 @ 10:00 a.m. EST |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, Dec. 12, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that its Board of Directors declared a quarterly dividend of $15.625 per share on its 6.25% Series B Mandatory Convertible Preferred Stock, payable on January 17, 2017, to holders of record on January 1, 2017. This equates to $0.78125 for each depositary share, which represents a 1/20th interest in a share of the Series B preferred stock. The dividend is for the period beginning on October 15, 2016 and ending on January 14, 2017.
The company has elected to pay this dividend in shares of common stock of the company to the extent permitted by the certificate of designations for the Series B preferred stock. Common shares issued will be listed and tradable on the New York Stock Exchange.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, Oct. 20, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the quarter ended September 30, 2016.
"During the third quarter, we once again delivered on our commitments and delivered solid results through our relentless focus on value creation in the current pricing environment," remarked Bill Way, President and Chief Executive Officer of Southwestern Energy. "As operations ramp up, we are also enhancing our laser focus on growing margins, evidenced this quarter by a reduction of lease operating expenses per unit for the fifth consecutive quarter. As we look forward to 2017, our capital rigor and commitment to balance sheet strength will remain central to delivering value-adding growth from our vast portfolio."
Highlights for the third quarter include:
Third Quarter of 2016 Financial Results
For the third quarter of 2016, Southwestern reported a net loss attributable to common stock of $735 million, or $1.52 per diluted share, and adjusted net income attributable to common stock (a non-GAAP measure) of $12 million, or $0.03 per diluted share. This compares to a net loss attributable to common stock of $1.8 billion, or $4.62 per diluted share, and an adjusted net income attributable to common stock of $3 million, or $0.01 per diluted share, in the third quarter of 2015.
Net cash provided by operating activities was $172 million for the third quarter of 2016, compared to $287 million in the third quarter of 2015. Net cash flow (a non-GAAP measure) was $173 million for the third quarter of 2016, compared to $330 million for the same period in 2015.
E&P Segment – The operating loss from the Company's E&P segment was $777 million for the third quarter of 2016, compared to an operating loss of $2.9 billion during the third quarter of 2015. The decreased operating loss was primarily due to a smaller non-cash impairment in 2016. Adjusted operating income from the Company's E&P segment was $42 million for the third quarter of 2016 (a non-GAAP measure), compared to an adjusted operating loss of $71 million for the same period in 2015. The increase in adjusted operating income was primarily due to lower operating costs and higher realized NGL prices partially offset by decreased realized natural gas prices and decreased production.
Net production totaled 211 Bcfe in the third quarter of 2016, down from 249 Bcfe in the third quarter of 2015 as a result of limited drilling and completion activity. The quarter included 90 Bcf from the Fayetteville Shale, 84 Bcf from Northeast Appalachia and 37 Bcfe from Southwest Appalachia. This compares to 118 Bcf from the Fayetteville Shale, 93 Bcf from Northeast Appalachia and 37 Bcfe from Southwest Appalachia in the third quarter of 2015.
Due to the continued challenging commodity price environment, Southwestern's average realized gas price including the effect of derivatives in the third quarter of 2016 was $1.73 per Mcf, down from $2.21 per Mcf in the third quarter of 2015. The Company's commodity derivative activities decreased its average realized gas price by $0.05 per Mcf during the third quarter of 2016, compared to an increase of $0.44 per Mcf during the same period in 2015. As of October 18, 2016, the Company had approximately 99 Bcf of its remaining 2016 forecasted gas production protected at an average swap or purchased put strike price of $2.84 per Mcf with upside exposure on approximately 50% of those protected volumes. Additionally, the Company had approximately 535 Bcf of its 2017 forecasted gas production protected at an average swap or purchased put strike price of $3.00 per Mcf with upside exposure on approximately 45%, or 239 Bcf, of those protected volumes to $3.33 per Mcf. The Company also had approximately 160 Bcf of its 2018 forecasted gas production protected at an average swap or purchased put strike price of $2.94 per Mcf, with upside exposure on approximately 89%, or 141 Bcf, of those protected volumes to $3.35 per Mcf.
A detailed breakdown of the Company's natural gas derivative financial instruments as of October 18, 2016 is shown below:
Weighted Average Price per MMBtu | |||||||||||||
Volume |
Swaps |
Sold Puts |
Purchased |
Sold Calls | |||||||||
Financial protection on production |
|||||||||||||
2016 |
|||||||||||||
Fixed price swaps |
51 |
$ |
2.81 |
$ |
– |
$ |
– |
$ |
– | ||||
Purchased put options |
4 |
$ |
– |
$ |
– |
$ |
2.34 |
$ |
– | ||||
Two-way costless-collars |
40 |
$ |
– |
$ |
– |
$ |
2.93 |
$ |
3.33 | ||||
Three-way costless-collars |
5 |
$ |
– |
$ |
2.30 |
$ |
3.00 |
$ |
3.25 | ||||
Total |
99 |
||||||||||||
2017 |
|||||||||||||
Fixed price swaps |
296 |
$ |
3.04 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless-collars |
103 |
$ |
– |
$ |
– |
$ |
2.94 |
$ |
3.38 | ||||
Three-way costless-collars |
135 |
$ |
– |
$ |
2.29 |
$ |
2.97 |
$ |
3.30 | ||||
Total |
535 |
||||||||||||
2018 |
|||||||||||||
Fixed price swaps |
18 |
$ |
3.00 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless-collars |
14 |
$ |
– |
$ |
– |
$ |
3.00 |
$ |
3.46 | ||||
Three-way costless-collars |
128 |
$ |
– |
$ |
2.31 |
$ |
2.93 |
$ |
3.33 | ||||
Total |
160 |
||||||||||||
Sold call options |
|||||||||||||
2016 |
30 |
$ |
– |
$ |
– |
$ |
– |
$ |
5.00 | ||||
2017 |
86 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.25 | ||||
2018 |
63 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.50 | ||||
2019 |
52 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.50 | ||||
2020 |
32 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.75 | ||||
Total |
263 |
Note: Amounts may not sum due to rounding |
Like most producers, the Company typically sells its natural gas at a discount to NYMEX settlement prices. This discount includes a basis differential, third-party transportation charges and fuel charges. Disregarding the impact of derivatives, the Company's average price received for its gas production during the third quarter of 2016 was approximately $1.03 per Mcf lower than average NYMEX settlement prices, compared to approximately $1.00 per Mcf lower than average NYMEX settlement prices during the third quarter of 2015.
As is historically the case, the Company experiences its widest differentials in the third quarter. This widening basis for the third quarter of 2016 was influenced largely by regional storage levels being at or near capacity. Factoring in the forecasted gains of approximately $0.03 per Mcf on basis hedges currently in place, the Company anticipates its total company basis differential to end the year at the high end of its guidance, which is $0.83 per Mcf. Based on current expectations, these gains for 2016 are expected to total over $20 million and will be reported as part of hedge gains.
The Company's basis hedging program includes protection associated with physical sales agreements that is reported as a component of realized gas price excluding derivatives and; therefore, is included in the gas basis differential and transportation charge guidance. This program also includes financial instruments with the results of which are reported as realized gas price including derivatives and are not included in guidance.
As of September 30, 2016, the Company mitigated the volatility of basis differentials by protecting basis on approximately 75 Bcf of the remaining 2016 expected natural gas production through financial derivative instruments and physical sales arrangements at a basis differential to NYMEX natural gas prices of approximately ($0.08) per Mcf. Additionally, the Company has protected basis on approximately 196 Bcf of its 2017 forecasted natural gas production at a basis differential to NYMEX natural gas prices of approximately ($0.33) per Mcf. Please refer to our quarterly report on Form 10-Q filed with the Securities and Exchange Commission, for additional information on the Company's commodity, basis and interest rate protection.
Lease operating expenses per unit of production for the Company's E&P segment were down to $0.86 per Mcfe in the third quarter of 2016, compared to $0.92 per Mcfe in the third quarter of 2015. The decrease was primarily due to the successful renegotiation of the existing gathering and processing rates in Southwest Appalachia.
General and administrative expenses per unit of production were $0.23 per Mcfe in the third quarter of 2016, compared to $0.20 per Mcfe in the third quarter of 2015. This increase was primarily due to the decreased volumes in 2016. This excludes the restructuring charges associated with the workforce reduction, which were $2 million for the E&P segment in the third quarter of 2016.
Taxes other than income taxes were flat at $0.10 per Mcfe in the third quarter of 2016 as compared to the third quarter of 2015. Taxes other than income taxes per Mcfe vary from period to period due to changes in severance and ad valorem taxes that result from the mix of the Company's production volumes and fluctuations in commodity prices.
The Company's full cost pool amortization rate declined significantly to $0.35 per Mcfe in the third quarter of 2016, compared to $0.98 per Mcfe in the third quarter of 2015. The amortization rate is impacted by the timing and amount of reserve additions, the costs associated with those additions, revisions of previous reserve estimates due to both price and well performance, write-downs that result from full cost ceiling impairments, proceeds from the sale of properties that reduce the full cost pool and the levels of costs subject to amortization. The Company cannot predict its future full cost pool amortization rate with accuracy due to the variability of each of the factors discussed above, as well as other factors, including but not limited to the uncertainty of the amount of future reserve changes.
Midstream – Operating income for the Company's Midstream segment, comprised of gathering and marketing activities, was $52 million for the third quarter of 2016, compared to $68 million for the same period in 2015. Adjusted operating income (a non-GAAP measure) for the Company's Midstream segment was $52 million for the third quarter of 2016, compared to $69 million for the same period in 2015. The decrease in operating income was largely due to a decrease in volumes gathered, resulting from lower production volumes in the Fayetteville Shale.
First Nine Months of 2016 Financial Results
For the first nine months of 2016, Southwestern reported a net loss attributable to common stock of $2.5 billion, or $6.02 per diluted share, and an adjusted net loss attributable to common stock (a non-GAAP measure) of $52 million, or $0.12 per diluted share. This compares to a net loss attributable to common stock of $2.5 billion, or $6.65 per diluted share, and an adjusted net income attributable to common stock of $77 million, or $0.20 per diluted share, in the first nine months of 2015.
Net cash provided by operating activities was $337 million for the first nine months of 2016, compared to $1.2 billion in the first nine months of 2015. Net cash flow (a non-GAAP measure) was $434 million for the first nine months of 2016, compared to $1.2 billion for the same period in 2015.
E&P Segment – The operating loss from the Company's E&P segment was $2.5 billion for the first nine months of 2016, compared to an operating loss of $4.5 billion during the first nine months of 2015. The decreased operating loss was primarily due to a smaller non-cash impairment in 2016. Adjusted operating loss from the Company's E&P segment was $91 million for the first nine months of 2016 (a non-GAAP measure), compared to an adjusted operating loss of $97 million for the same period in 2015. The improvement in adjusted operating loss was primarily due to lower operating costs partially offset by lower realized natural gas prices and decreased production.
Net production totaled 673 Bcfe in the first nine months of 2016, down from 727 Bcfe in the first nine months of 2015. The first nine months of 2016 included 289 Bcf from the Fayetteville Shale, 268 Bcf from Northeast Appalachia and 115 Bcfe from Southwest Appalachia. This compares to 354 Bcf from the Fayetteville Shale, 263 Bcf from Northeast Appalachia and 103 Bcfe from Southwest Appalachia in the first nine months of 2015.
Due to the continued challenging commodity price environment, in the first nine months of 2016, Southwestern's average realized gas price including the effect of derivatives was $1.51 per Mcf, down from $2.47 per Mcf in the first nine months of 2015. The Company's commodity derivative activities increased its average realized gas price by $0.04 per Mcf during the first nine months of 2016, compared to an increase of $0.42 per Mcf during the same period in 2015. Disregarding the impact of derivatives, the Company's average price received for its gas production during the first nine months of 2016 was approximately $0.82 per Mcf lower than average NYMEX settlement prices, compared to approximately $0.75 per Mcf lower than average NYMEX settlement prices during the first nine months of 2015.
Lease operating expenses per unit of production for the Company's E&P segment declined to $0.87 per Mcfe in the first nine months of 2016, compared to $0.92 per Mcfe in the first nine months of 2015. The decrease was primarily due to reduced workover activity and contract services as well as the successful renegotiation of the existing gathering and processing rates in Southwest Appalachia.
General and administrative expenses per unit of production decreased to $0.21 per Mcfe in the first nine months of 2016, compared to $0.22 per Mcfe in the first nine months quarter of 2015. The lower employee costs in 2016 more than offset the impact of declining production volumes. This excludes the restructuring charges associated with the workforce reduction, which were $71 million for the E&P segment in the first nine months of 2016.
Taxes other than income taxes were down to $0.09 per Mcfe in the first nine months of 2016, compared to $0.11 per Mcfe in the first nine months of 2015. This excludes the restructuring charges associated with the workforce reduction, which were $3 million for the E&P segment in the first nine months of 2016.
The Company's full cost pool amortization rate declined significantly to $0.40 per Mcfe in the first nine months of 2016, compared to $1.08 per Mcfe in the first nine months of 2015.
Midstream – Operating income for the Company's Midstream segment was $169 million for the first nine months of 2016, compared to $511 million for the same period in 2015. The decrease in operating income was primarily due to 2015 including a $277 million gain on sale of assets divested. Adjusted operating income (a non-GAAP measure) for the Company's Midstream segment was $172 million for the first nine months of 2016, excluding the impacts from restructuring charges, compared to $234 million for the same period in 2015, which excluded a $277 million gain on sale of assets divested. The decrease in adjusted operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale and the sale of the Company's northeast Pennsylvania gathering assets.
Capital Structure and Investments – At September 30, 2016, the Company had total debt of approximately $4.7 billion and $3.2 billion in net debt (a non-GAAP measure).
As of September 30, 2016, there were no borrowings under the Company's revolving credit facilities; however, $174 million in letters of credit was outstanding under the new revolving credit facility. As a result of the equity offering closed in July 2016, the Company repaid $375 million of its $750 million term loan originally due in November 2018, which extended the maturity on this term loan to December 2020, subject to certain conditions. The Company paid down an additional $48 million following the closing of the previously announced sale of approximately 55,000 net acres in West Virginia. At September 30, 2016, the Company has $317 million in remaining 2017 and 2018 debt maturities, well below the $1.0 billion at December 31, 2015 and also well below the $1.5 billion cash balance.
During the first nine months of 2016, Southwestern invested a total of $376 million. This is down from $2.1 billion in the first nine months of 2015. The $376 million includes approximately $372 million invested in its E&P business, $3 million invested in its Midstream segment and $1 million invested for corporate and other purposes. Of the $376 million, approximately $123 million was associated with capitalized interest and $62 million was associated with capitalized expenses.
E&P Operations Review
During the first nine months of 2016, Southwestern invested approximately $372 million in its E&P business, including $189 million in investment capital and $183 in capitalized interest and expenses.
In Northeast Appalachia, the Company had net gas production of 84 Bcf in the third quarter of 2016, compared to 93 Bcf in the third quarter of 2015. In the third quarter of 2016, it invested $52 million, drilling 18 wells, completing 9 wells and placing 3 wells on production. Gross operated production in Northeast Appalachia was approximately 1,046 MMcf per day at September 30, 2016. The Company plans to place 21 wells on production in the fourth quarter of 2016.
During the third quarter, Northeast Appalachia drilled 18 wells utilizing advanced techniques, such as the use of rotary steerable tools, that resulted in an average drill to total depth of less than 8 days from re-entry to re-entry which is 5 percent faster than when the Company paused operations at the end of 2015. Included in these results was a well that drilled over 4,700 feet in 24 hours, a record for the Company in Northeast Appalachia. A number of the nine horizontal wells completed used a new completion design based on higher intensity stimulation. This, when coupled with optimized flow techniques, showed very encouraging early results. For example, the Racine pad, located in Susquehanna County, came online at greater than 50 million cubic feet per day from 3 wells, materially better than the previous offset wells.
In Southwest Appalachia, the Company invested $41 million during the third quarter of 2016, drilling 4 wells and completing 8 wells, the first of which is expected to be placed to sales in the fourth quarter of 2016. Net production was flat at 37 Bcfe in the third quarter of 2016 as compared to the third quarter of 2015. The gross operated production rate in Southwest Appalachia was approximately 621 MMcfe per day at September 30, 2016. Southwestern plans to place 9 wells on production in the fourth quarter of 2016.
The Company continues to focus on margin improvements and has reduced its lease operating expenses in Southwest Appalachia to $1.06 per Mcfe in the first nine months of 2016, compared to $1.39 per Mcfe in the first nine months of 2015. The reduction is a result of the successful renegotiation of its gathering and processing rates as well as operating efficiencies implemented throughout the year.
In the third quarter, Southwest Appalachia continued to realize efficiencies in its drilling and completions operations. Throughout the restart of activity, re-entry to re-entry days decreased and stages completed per day increased compared to the fourth quarter of 2015. Additionally, the Company continued to test tighter stage spacing, leveraging its learnings from previous tests such as the continued outperformance of the Alice Edge pad, which was brought online in the fourth quarter of 2015. Tighter stage spaced wells are continuing to perform materially better on an estimated ultimate recovery per foot basis than offset wells.
The Company achieved a monumental milestone in the Fayetteville Shale during the third quarter of 2016, surpassing 5 Tcf of cumulative production since its inception. After over a decade of development, this asset continues to account for approximately two percent of the nation's natural gas supply and remains a significant value creator for the Company.
In the Fayetteville Shale, Southwestern invested $17 million, drilling 1 well, completing 8 wells and placing 6 wells to sales in the third quarter of 2016. Net gas production was 90 Bcf in the third quarter of 2016, compared to 118 Bcf in the third quarter of 2015. Gross operated gas production in the Fayetteville Shale was approximately 1,443 MMcf per day at September 30, 2016. The company plans to place 22 wells on production in the fourth quarter of 2016.
The 6 wells in this operating area placed on production in the third quarter had an average initial production rate of 6,701 Mcf per day. Similar to the other operating areas, the Company is currently testing increased proppant volumes which are over two times greater than historical well completions in the Fayetteville Shale. Additionally, Southwestern is continuing testing of its concept surrounding the Moorefield Shale as it progresses its efforts to lower the breakeven prices in the Fayetteville operating area.
Company-wide as of September 30, Southwestern had 101 wells that were either waiting on completion or waiting to be placed to sales, including 37 in Northeast Appalachia, 36 in Southwest Appalachia and 28 in Fayetteville. The Company expects to exit 2016 with approximately 85 drilled but uncompleted wells, returning to a normal maintenance level for efficient operations of approximately 60 by early 2017.
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures as of and for the three and nine months ended September 30, 2016 and September 30, 2015, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net loss attributable to common stock |
$ |
(735) |
$ |
(1,766) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
(2) |
(0) | |||
Impairment of natural gas and oil properties |
817 |
2,839 | |||
Restructuring charges |
2 |
1 | |||
Loss on sale of assets, net |
– |
1 | |||
Loss on early extinguishment of debt and other (1) |
57 |
– | |||
Transaction costs |
– |
1 | |||
(Gain) loss on certain derivatives |
(81) |
34 | |||
Adjustments due to inventory valuation |
(1) |
– | |||
Adjustments due to discrete tax items (2) |
256 |
– | |||
Tax impact on adjustments |
(301) |
(1,107) | |||
Adjusted net income attributable to common stock |
$ |
12 |
$ |
3 | |
(1) |
Includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
2016 primarily relates to the exclusion of certain discrete tax adjustments in the third quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
Diluted earnings per share: |
|||||
Diluted earnings per share |
$ |
(1.52) |
$ |
(4.62) | |
Add back: |
|||||
Participating securities - mandatory convertible preferred stock |
(0.00) |
(0.00) | |||
Impairment of natural gas and oil properties |
1.69 |
7.43 | |||
Restructuring charges |
0.01 |
0.00 | |||
Loss on sale of assets, net |
– |
0.00 | |||
Loss on early extinguishment of debt and other (1) |
0.12 |
– | |||
Transaction costs |
– |
0.00 | |||
(Gain) loss on certain derivatives |
(0.17) |
0.09 | |||
Adjustments due to inventory valuation |
(0.00) |
– | |||
Adjustments due to discrete tax items(2) |
0.53 |
– | |||
Tax impact on adjustments |
(0.63) |
(2.89) | |||
Adjusted diluted earnings per share |
$ |
0.03 |
$ |
0.01 | |
(1) |
Includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
2016 primarily relates to the exclusion of certain discrete tax adjustments in the third quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0% before the impacts of any valuation allowance. |
9 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net loss attributable to common stock |
$ |
(2,514) |
$ |
(2528) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
– |
(14) | |||
Impairment of natural gas and oil properties |
2,321 |
4,374 | |||
Restructuring charges |
77 |
1 | |||
Gain on sale of assets, net |
(2) |
(276) | |||
Loss on early extinguishment of debt and other (1) |
57 |
– | |||
Transaction costs |
– |
53 | |||
Loss on certain derivatives |
48 |
105 | |||
Adjustments due to inventory valuation |
3 |
– | |||
Adjustments due to discrete tax items (2) |
903 |
– | |||
Tax impact on adjustments |
(945) |
(1,638) | |||
Adjusted net income (loss) attributable to common stock |
$ |
(52) |
$ |
77 | |
(1) |
Includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
2016 primarily relates to the exclusion of certain discrete tax adjustments in the third quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0% before the impacts of any valuation allowance. |
9 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
Diluted earnings per share: |
|||||
Diluted earnings per share |
$ |
(6.02) |
$ |
(6.65) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
– |
(0.04) | |||
Impairment of natural gas and oil properties |
5.56 |
11.51 | |||
Restructuring charges |
0.19 |
0.00 | |||
Gain on sale of assets, net |
(0.01) |
(0.73) | |||
Loss on early extinguishment of debt and other(1) |
0.14 |
– | |||
Transaction costs |
– |
0.14 | |||
Loss on certain derivatives |
0.12 |
0.28 | |||
Adjustments due to inventory valuation |
0.01 |
– | |||
Adjustments due to discrete tax items (2) |
2.16 |
– | |||
Tax impact on adjustments |
(2.27) |
(4.31) | |||
Adjusted diluted earnings per share |
$ |
(0.12) |
$ |
0.20 | |
(1) |
Includes a $51 million loss for the redemption of certain senior notes and a $6 million loss related to the unamortized debt issuance costs and debt discounts associated with the extinguished debt which were included in other interest charges. |
(2) |
2016 primarily relates to the exclusion of certain discrete tax adjustments in the third quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0% before the impacts of any valuation allowance. |
3 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
172 |
$ |
287 | |
Add back: |
|||||
Changes in operating assets and liabilities |
– |
43 | |||
Restructuring charges |
1 |
– | |||
Net Cash Flow |
$ |
173 |
$ |
330 | |
9 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
337 |
$ |
1,227 | |
Add back: |
|||||
Changes in operating assets and liabilities |
50 |
(65) | |||
Restructuring charges |
47 |
– | |||
Net Cash Flow |
$ |
434 |
$ |
1,162 | |
3 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating loss |
$ |
(777) |
$ |
(2,910) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
817 |
2,839 | |||
Restructuring charges |
2 |
– | |||
Adjusted E&P segment operating income (loss) |
$ |
42 |
$ |
(71) | |
9 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating loss |
$ |
(2,486) |
$ |
(4,471) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
2,321 |
4,374 | |||
Restructuring charges |
74 |
– | |||
Adjusted E&P segment operating loss |
$ |
(91) |
$ |
(97) | |
3 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Midstream segment operating income: |
|||||
Midstream segment operating income |
$ |
52 |
$ |
68 | |
Add back: |
|||||
Loss on sale of assets, net |
– |
1 | |||
Adjusted Midstream segment operating income |
$ |
52 |
$ |
69 | |
9 Months Ended Sept 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Midstream segment operating income: |
|||||
Midstream segment operating income |
$ |
169 |
$ |
511 | |
Add back: |
|||||
Restructuring charges |
3 |
– | |||
Gain on sale of assets, net |
– |
(277) | |||
Adjusted Midstream segment operating income |
$ |
172 |
$ |
234 | |
September 30, |
June 30, | ||||
2016 |
2016 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
4,652 |
$ |
5,768 | |
Subtract: |
|||||
Cash and cash equivalents |
(1,474) |
(998) | |||
Net debt |
$ |
3,178 |
$ |
4,770 |
Southwestern management will host a teleconference call on Friday, October 21, 2016 at 10:00 a.m. Eastern to discuss its third quarter 2016 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
OPERATING STATISTICS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the nine months ended | |||||||||||
September 30, |
September 30, | |||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
Exploration & Production |
||||||||||||
Production |
||||||||||||
Gas production (Bcf) |
189 |
228 |
605 |
673 | ||||||||
Oil production (MBbls) |
536 |
562 |
1,729 |
1,696 | ||||||||
NGL production (MBbls) |
3,068 |
3,034 |
9,580 |
7,374 | ||||||||
Total production (Bcfe) |
211 |
249 |
673 |
727 | ||||||||
Commodity Prices |
||||||||||||
Average realized gas price per Mcf, including derivatives |
$ |
1.73 |
$ |
2.21 |
$ |
1.51 |
$ |
2.47 | ||||
Average realized gas price per Mcf, excluding derivatives |
$ |
1.78 |
$ |
1.77 |
$ |
1.47 |
$ |
2.05 | ||||
Average realized oil price per Bbl |
$ |
35.41 |
$ |
33.50 |
$ |
28.53 |
$ |
35.23 | ||||
Average realized NGL price per Bbl |
$ |
7.04 |
$ |
4.72 |
$ |
6.11 |
$ |
6.43 | ||||
Summary of Derivative Activity in the Statement of Operations |
||||||||||||
Settled commodity amounts included in "Operating Revenues" (in millions) |
$ |
– |
$ |
50 |
$ |
– |
$ |
145 | ||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(9) |
$ |
49 |
$ |
22 |
$ |
137 | ||||
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
81 |
$ |
(33) |
$ |
(45) |
$ |
(103) | ||||
Average unit costs per Mcfe |
||||||||||||
Lease operating expenses |
$ |
0.86 |
$ |
0.92 |
$ |
0.87 |
$ |
0.92 | ||||
General & administrative expenses (1) |
$ |
0.23 |
$ |
0.20 |
$ |
0.21 |
$ |
0.22 | ||||
Taxes, other than income taxes (2) |
$ |
0.10 |
$ |
0.10 |
$ |
0.09 |
$ |
0.11 | ||||
Full cost pool amortization |
$ |
0.35 |
$ |
0.98 |
$ |
0.40 |
$ |
1.08 | ||||
Midstream |
||||||||||||
Volumes marketed (Bcfe) |
264 |
288 |
814 |
837 | ||||||||
Volumes gathered (Bcf) |
145 |
186 |
463 |
620 |
(1) |
Excludes $2 million and $71 million of restructuring charges for the three and nine months ended September 30, 2016, respectively. |
(2) |
Excludes $3 million of restructuring charges for the nine months ended September 30, 2016. |
STATEMENTS OF OPERATIONS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the nine months ended | |||||||||||
September 30, |
September 30, | |||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
(in millions, except share/per share amounts) | ||||||||||||
Operating Revenues |
||||||||||||
Gas sales |
$ |
340 |
$ |
458 |
$ |
906 |
$ |
1,540 | ||||
Oil sales |
19 |
19 |
50 |
60 | ||||||||
NGL sales |
22 |
14 |
59 |
47 | ||||||||
Marketing |
237 |
216 |
631 |
663 | ||||||||
Gas gathering |
33 |
42 |
106 |
136 | ||||||||
651 |
749 |
1,752 |
2,446 | |||||||||
Operating Costs and Expenses |
||||||||||||
Marketing purchases |
234 |
213 |
627 |
654 | ||||||||
Operating expenses |
139 |
176 |
455 |
507 | ||||||||
General and administrative expenses |
61 |
60 |
171 |
188 | ||||||||
Restructuring charges |
2 |
– |
77 |
– | ||||||||
Depreciation, depletion and amortization |
99 |
275 |
349 |
876 | ||||||||
Impairment of natural gas and oil properties |
817 |
2,839 |
2,321 |
4,374 | ||||||||
(Gain) loss on sale of assets, net |
– |
1 |
– |
(276) | ||||||||
Taxes, other than income taxes |
24 |
27 |
69 |
84 | ||||||||
1,376 |
3,591 |
4,069 |
6,407 | |||||||||
Operating Loss |
(725) |
(2,842) |
(2,317) |
(3,961) | ||||||||
Interest Expense |
||||||||||||
Interest on debt |
59 |
51 |
168 |
153 | ||||||||
Other interest charges |
8 |
2 |
12 |
54 | ||||||||
Interest capitalized |
(41) |
(53) |
(123) |
(155) | ||||||||
26 |
– |
57 |
52 | |||||||||
Gain (Loss) on Derivatives |
71 |
15 |
(28) |
30 | ||||||||
Loss on Early Extinguishment of Debt |
(51) |
– |
(51) |
– | ||||||||
Other Income, Net |
3 |
– |
– |
2 | ||||||||
Loss Before Income Taxes |
(728) |
(2,827) |
(2,453) |
(3,981) | ||||||||
Provision (Benefit) for Income Taxes |
||||||||||||
Current |
– |
– |
– |
7 | ||||||||
Deferred |
(20) |
(1,088) |
(20) |
(1,539) | ||||||||
(20) |
(1,088) |
(20) |
(1,532) | |||||||||
Net Loss |
(708) |
(1,739) |
(2,433) |
(2,449) | ||||||||
Mandatory convertible preferred stock dividend |
27 |
27 |
81 |
79 | ||||||||
Net Loss Attributable to Common Stock |
$ |
(735) |
$ |
(1,766) |
$ |
(2,514) |
$ |
(2,528) | ||||
Loss Per Common Share |
||||||||||||
Basic |
$ |
(1.52) |
$ |
(4.62) |
$ |
(6.02) |
$ |
(6.65) | ||||
Diluted |
$ |
(1.52) |
$ |
(4.62) |
$ |
(6.02) |
$ |
(6.65) | ||||
Weighted Average Common Shares Outstanding | ||||||||||||
Basic |
482,485,150 |
382,098,080 |
417,222,661 |
379,909,748 | ||||||||
Diluted |
482,485,150 |
382,098,080 |
417,222,661 |
379,909,748 |
BALANCE SHEETS (Unaudited) |
|||||||||||
Southwestern Energy Company and Subsidiaries |
|||||||||||
September 30, 2016 |
December 31, | ||||||||||
(in millions) | |||||||||||
ASSETS |
|||||||||||
Current assets |
$ |
1,889 |
$ |
393 | |||||||
Property and equipment |
24,290 |
24,364 | |||||||||
Less: Accumulated depreciation, depletion and amortization |
(19,501) |
(16,821) | |||||||||
Total property and equipment, net |
4,789 |
7,543 | |||||||||
Other long-term assets |
212 |
150 | |||||||||
Total assets |
6,890 |
8,086 | |||||||||
LIABILITIES AND EQUITY |
|||||||||||
Current liabilities |
649 |
707 | |||||||||
Long-term debt |
4,651 |
4,704 | |||||||||
Pension and other postretirement liabilities |
51 |
50 | |||||||||
Other long-term liabilities |
416 |
343 | |||||||||
Total liabilities |
5,767 |
5,804 | |||||||||
Equity: |
|||||||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 493,446,371 shares as of September 30, 2016 (does not include 2,043,780 shares issued on October 17, 2016, on account of a dividend declared on September 21, 2016) and 390,138,549 as of December 31, 2015 |
5 |
4 | |||||||||
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of September 30, 2016 and December 31, 2015, conversion in January 2018 |
– |
– | |||||||||
Additional paid-in capital |
4,673 |
3,409 | |||||||||
Accumulated deficit |
(3,515) |
(1,082) | |||||||||
Accumulated other comprehensive loss |
(39) |
(48) | |||||||||
Common stock in treasury; 31,269 shares as of September 30, 2016 and 47,149 as of December 31, 2015 |
(1) |
(1) | |||||||||
Total equity |
1,123 |
2,282 | |||||||||
Total liabilities and equity |
$ |
6,890 |
$ |
8,086 | |||||||
STATEMENTS OF CASH FLOWS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
For the nine months ended | ||||||
September 30, | ||||||
2016 |
2015 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities |
||||||
Net loss |
$ |
(2,433) |
$ |
(2,449) | ||
Adjustments to reconcile net loss to net cash provided by operating |
||||||
Depreciation, depletion and amortization |
349 |
877 | ||||
Impairment of natural gas and oil properties |
2,321 |
4,374 | ||||
Amortization of debt issuance costs |
12 |
50 | ||||
Deferred income taxes |
(20) |
(1,539) | ||||
Loss on derivatives, net of settlement |
48 |
105 | ||||
Stock-based compensation |
24 |
18 | ||||
Gain on sales of assets, net |
– |
(276) | ||||
Restructuring charges |
30 |
– | ||||
Loss on early extinguishment of debt |
51 |
– | ||||
Other |
5 |
2 | ||||
Change in assets and liabilities |
(50) |
65 | ||||
Net cash provided by operating activities |
337 |
1,227 | ||||
Cash Flows From Investing Activities |
||||||
Capital investments |
(391) |
(1,392) | ||||
Acquisitions |
– |
(582) | ||||
Proceeds from sale of property and equipment |
434 |
704 | ||||
Other |
– |
7 | ||||
Net cash provided by (used in) investing activities |
43 |
(1,263) | ||||
Cash Flows From Financing Activities |
||||||
Payments on current portion of long-term debt |
(1) |
(1) | ||||
Payments on long-term debt |
(1,175) |
(500) | ||||
Payments on short-term debt |
– |
(4,500) | ||||
Payments on revolving credit facility |
(3,268) |
(2,168) | ||||
Borrowings under revolving credit facility |
3,152 |
2,148 | ||||
Payments on commercial paper |
(242) |
(5,179) | ||||
Borrowings under commercial paper |
242 |
5,699 | ||||
Change in bank drafts outstanding |
(19) |
26 | ||||
Proceeds from issuance of long-term debt |
1,191 |
2,200 | ||||
Debt issuance costs |
(17) |
(17) | ||||
Proceeds from issuance of common stock |
1,247 |
669 | ||||
Proceeds from issuance of mandatory convertible preferred stock |
– |
1,673 | ||||
Preferred stock dividend |
(27) |
(52) | ||||
Other |
(4) |
– | ||||
Net cash provided by (used in) financing activities |
1,079 |
(2) | ||||
Increase (decrease) in cash and cash equivalents |
1,459 |
(38) | ||||
Cash and cash equivalents at beginning of year |
15 |
53 | ||||
Cash and cash equivalents at end of period |
$ |
1,474 |
$ |
15 |
SEGMENT INFORMATION (Unaudited) |
|||||||||||||||
Southwestern Energy Company and Subsidiaries |
Exploration |
||||||||||||||
and |
|||||||||||||||
Production |
Midstream |
Other |
Eliminations |
Total | |||||||||||
(in millions) | |||||||||||||||
Three months ended September 30, 2016 |
|||||||||||||||
Revenues |
$ |
378 |
$ |
682 |
$ |
– |
$ |
(409) |
$ |
651 | |||||
Marketing purchases |
– |
578 |
– |
(344) |
234 | ||||||||||
Operating expenses |
181 |
23 |
– |
(65) |
139 | ||||||||||
General and administrative expenses |
50 |
11 |
– |
– |
61 | ||||||||||
Restructuring charges |
2 |
– |
– |
– |
2 | ||||||||||
Depreciation, depletion and amortization |
83 |
16 |
– |
– |
99 | ||||||||||
Impairment of natural gas and oil properties |
817 |
– |
– |
– |
817 | ||||||||||
Taxes, other than income taxes |
22 |
2 |
– |
– |
24 | ||||||||||
Operating income (loss) |
(777) |
52 |
– |
– |
(725) | ||||||||||
Capital investments(1) |
179 |
1 |
– |
– |
180 | ||||||||||
Three months ended September 30, 2015 |
|||||||||||||||
Revenues |
$ |
488 |
$ |
747 |
$ |
– |
$ |
(486) |
$ |
749 | |||||
Marketing purchases |
– |
615 |
– |
(402) |
213 | ||||||||||
Operating expenses |
228 |
32 |
– |
(84) |
176 | ||||||||||
General and administrative expenses |
50 |
10 |
– |
– |
60 | ||||||||||
Depreciation, depletion and amortization |
255 |
20 |
– |
– |
275 | ||||||||||
Impairment of natural gas and oil properties |
2,839 |
– |
– |
– |
2,839 | ||||||||||
(Gain) loss on sale of assets, net |
– |
1 |
– |
– |
1 | ||||||||||
Taxes, other than income taxes |
26 |
1 |
– |
– |
27 | ||||||||||
Operating income (loss) |
(2,910) |
68 |
– |
– |
(2,842) | ||||||||||
Capital investments(1) |
461 |
7 |
– |
– |
468 | ||||||||||
Nine months ended September 30, 2016 |
|||||||||||||||
Revenues |
$ |
998 |
$ |
1,862 |
$ |
– |
$ |
(1,108) |
$ |
1,752 | |||||
Marketing purchases |
– |
1,533 |
– |
(906) |
627 | ||||||||||
Operating expenses |
586 |
71 |
– |
(202) |
455 | ||||||||||
General and administrative expenses |
141 |
30 |
– |
– |
171 | ||||||||||
Restructuring charges |
74 |
3 |
– |
– |
77 | ||||||||||
Depreciation, depletion and amortization |
300 |
49 |
– |
– |
349 | ||||||||||
Impairment of natural gas and oil properties |
2,321 |
– |
– |
– |
2,321 | ||||||||||
Taxes, other than income taxes |
62 |
7 |
– |
– |
69 | ||||||||||
Operating income (loss) |
(2,486) |
169 |
– |
– |
(2,317) | ||||||||||
Capital investments(1) |
372 |
3 |
1 |
– |
376 | ||||||||||
Nine months ended September 30, 2015 |
|||||||||||||||
Revenues |
$ |
1,633 |
$ |
2,451 |
$ |
1 |
$ |
(1,639) |
$ |
2,446 | |||||
Marketing purchases |
– |
2,025 |
– |
(1,371) |
654 | ||||||||||
Operating expenses |
670 |
103 |
2 |
(268) |
507 | ||||||||||
General and administrative expenses |
158 |
30 |
– |
– |
188 | ||||||||||
Depreciation, depletion and amortization |
824 |
52 |
– |
– |
876 | ||||||||||
Impairment of natural gas and oil properties |
4,374 |
– |
– |
– |
4,374 | ||||||||||
(Gain) loss on sale of assets, net |
1 |
(277) |
– |
– |
(276) | ||||||||||
Taxes, other than income taxes |
77 |
7 |
– |
– |
84 | ||||||||||
Operating income (loss) |
(4,471) |
511 |
(1) |
– |
(3,961) | ||||||||||
Capital investments(1) |
1,880 |
164 |
10 |
– |
2,054 |
(1) |
Capital investments includes increases of $27 million and $6 million for the three months ended September 30, 2016 and 2015, respectively, and decreases of $24 million and $5 million for the nine months ended September 30, 2016 and 2015, respectively, relating to the change in accrued expenditures between periods. E&P capital for the nine months ended September 30, 2015 includes approximately $516 million related to the WPX Property and Statoil Property Acquisitions. Midstream capital for the nine months ended September 30, 2015 includes approximately $119 million associated with the intangible asset related to the firm transportation acquired through the WPX Property Acquisition. |
SOURCE Southwestern Energy Company
HOUSTON, Oct. 10, 2016 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2016 Third Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, October 21, 2016, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Third Quarter 2016 Earnings |
When: |
October 21, 2016 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, Oct. 10, 2016 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2016 Third Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, October 21, 2016, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Third Quarter 2016 Earnings |
When: |
October 21, 2016 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, Sept. 21, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that an authorized committee of its Board of Directors declared a quarterly dividend of $15.625 per share on its 6.25% Series B Mandatory Convertible Preferred Stock, payable on October 17, 2016, to holders of record on October 1, 2016. This equates to $0.78125 for each depositary share, which represents a 1/20th interest in a share of the Series B preferred stock. The dividend is for the period beginning on July 15, 2016 and ending on October 14, 2016.
The company has elected to pay this dividend in shares of common stock of the company to the extent permitted by the certificate of designations for the Series B preferred stock. Common shares issued will be listed and tradable on the New York Stock Exchange.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, July 21, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the quarter ended June 30, 2016.
"The second quarter was a defining time at Southwestern Energy, where we delivered on our strategic commitments of strengthening our balance sheet, enhancing margins and optimizing our portfolio," remarked Bill Way, President and Chief Executive Officer of Southwestern Energy. "As promised, we took significant and deliberate steps this quarter to strengthen our balance sheet that, when combined with the continued outperformance by our assets, positions us to reinitiate drilling and completion activities and accelerate our path to value-adding growth. We are excited as we drive into the second half of the year and build momentum toward the future." Highlights include:
Second Quarter of 2016 Financial Results
For the second quarter of 2016, Southwestern reported a net loss attributable to common stock of $620 million, or $1.61 per diluted share, and an adjusted net loss attributable to common stock (reconciled below) of $34 million, or $0.09 per diluted share. This compares to a net loss attributable to common stock of $815 million, or $2.13 per diluted share, and an adjusted net loss attributable to common stock of $9 million, or $0.02 per diluted share, in the second quarter of 2015.
Net cash provided by operating activities was $73 million for the second quarter of 2016, compared to $399 million in the second quarter of 2015. Net cash flow (reconciled below) was $114 million for the second quarter of 2016, compared to $339 million for the same period in 2015.
E&P Segment – The operating loss from the Company's E&P segment was $549 million for the second quarter of 2016, compared to an operating loss of $1.6 billion during the second quarter of 2015. The decreased operating loss was primarily due to a smaller non-cash impairment. The adjusted operating loss from the Company's E&P segment was $68 million for the second quarter of 2016 (reconciled below), when excluding the non-cash impairment and restructuring charges, compared to an adjusted operating loss of $104 million for the same period in 2015. The decreased adjusted operating loss was primarily due to lower operating costs and higher realized NGL prices partially offset by lower realized natural gas prices and decreased production.
Net production totaled 225 Bcfe in the second quarter of 2016, down less than anticipated from the 245 Bcfe in the second quarter of 2015. The quarter included 96 Bcf from the Fayetteville Shale, 90 Bcf from Northeast Appalachia and 38 Bcfe from Southwest Appalachia. This compares to 121 Bcf from the Fayetteville Shale, 87 Bcf from Northeast Appalachia and 35 Bcfe from Southwest Appalachia in the second quarter of 2015.
Due to the continued challenging commodity price environment, including the effect of derivatives, Southwestern's average realized gas price in the second quarter of 2016 was $1.32 per Mcf, down from $2.23 per Mcf in the second quarter of 2015. The Company's commodity derivative activities increased its average realized gas price by $0.11 per Mcf during the second quarter of 2016, compared to an increase of $0.47 per Mcf during the same period in 2015. As of July 19, 2016, the Company had approximately 93 Bcf of its remaining 2016 forecasted gas production protected at an average floor price of $2.57 per Mcf with upside exposure on approximately 34% of those protected volumes. Additionally, the Company had approximately 228 Bcf of its 2017 forecasted gas production protected at an average floor price of $3.01 per Mcf with upside exposure on approximately 29%, or 66 Bcf, of those protected volumes to $3.39 per Mcf.
A detailed breakdown of the Company's derivative financial instruments as of July 19, 2016 is shown below:
Weighted Average Price per MMBtu | |||||||||||||
Volume (Bcf) |
Swaps |
Sold Puts |
Purchased Puts |
Sold Calls | |||||||||
Financial protection on production |
|||||||||||||
2016 |
|||||||||||||
Fixed price swaps |
61 |
$ |
2.57 |
$ |
– |
$ |
– |
$ |
– | ||||
Purchased put options |
17 |
$ |
– |
$ |
– |
$ |
2.34 |
$ |
– | ||||
Two-way costless-collars |
15 |
$ |
– |
$ |
– |
$ |
2.81 |
$ |
3.38 | ||||
Total |
93 |
||||||||||||
2017 |
|||||||||||||
Fixed price swaps |
163 |
$ |
3.07 |
$ |
– |
$ |
– |
$ |
– | ||||
Two-way costless-collars |
47 |
$ |
– |
$ |
– |
$ |
2.90 |
$ |
3.33 | ||||
Three-way costless-collars |
18 |
$ |
– |
$ |
2.25 |
$ |
2.75 |
$ |
3.56 | ||||
Total |
228 |
||||||||||||
Sold call options |
|||||||||||||
2016 |
60 |
$ |
– |
$ |
– |
$ |
– |
$ |
5.00 | ||||
2017 |
86 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.25 | ||||
2018 |
63 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.50 | ||||
2019 |
52 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.50 | ||||
2020 |
32 |
$ |
– |
$ |
– |
$ |
– |
$ |
3.75 | ||||
Total |
293 |
Like most producers, the Company typically sells its natural gas at a discount to NYMEX settlement prices. This discount includes a basis differential, third-party transportation charges and fuel charges. Disregarding the impact of derivatives, the Company's average price received for its gas production during the second quarter of 2016 was approximately $0.74 per Mcf lower than average NYMEX settlement prices, compared to approximately $0.88 per Mcf lower than average NYMEX settlement prices during the second quarter of 2015. As of June 30, 2016, the Company attempted to mitigate the volatility of basis differentials by protecting basis on approximately 118 Bcf of the remaining 2016 expected natural gas production through financial derivative instruments and physical sales arrangements at a basis differential to NYMEX natural gas prices of approximately ($0.13) per Mcf. Additionally, the Company has protected basis on approximately 105 Bcf of its 2017 forecasted natural gas production at a basis differential to NYMEX natural gas prices of approximately ($0.10) per Mcf.
Lease operating expenses per unit of production for the Company's E&P segment were down to $0.87 per Mcfe in the second quarter of 2016, compared to $0.93 per Mcfe in the second quarter of 2015. The decrease was primarily due to reduced workover activity and contract services as well as the successful renegotiation of the existing gathering and processing rates in Southwest Appalachia.
General and administrative expenses per unit of production were flat at $0.21 per Mcfe in the second quarter of 2016 as compared to the second quarter of 2015. General and administrative cost reductions were offset by decreased production volumes. This excludes the restructuring charges associated with the workforce reduction, which were $11 million for the E&P segment in the second quarter of 2016.
Taxes other than income taxes were down to $0.09 per Mcfe in the second quarter of 2016, compared to $0.10 per Mcfe in the second quarter of 2015. Taxes other than income taxes per Mcfe vary from period to period due to changes in severance and ad valorem taxes that result from the mix of the Company's production volumes and fluctuations in commodity prices.
The Company's full cost pool amortization rate declined significantly to $0.35 per Mcfe in the second quarter of 2016, compared to $1.13 per Mcfe in the second quarter of 2015. The amortization rate is impacted by the timing and amount of reserve additions, the costs associated with those additions, revisions of previous reserve estimates due to both price and well performance, write-downs that result from full cost ceiling tests, proceeds from the sale of properties that reduce the full cost pool and the levels of costs subject to amortization. The Company cannot predict its future full cost pool amortization rate with accuracy due to the variability of each of the factors discussed above, as well as other factors.
Midstream – Operating income for the Company's Midstream segment, comprised of gathering and marketing activities, was $57 million for the second quarter of 2016, compared to $355 million for the same period in 2015. The decrease in operating income was primarily due to 2015 including a $278 million gain on sale of assets divested. Adjusted operating income (reconciled below) for the Company's Midstream segment was $57 million for the second quarter of 2016. This is down from adjusted operating income of $77 million, which excluded a $278 million gain on sale of assets divested, for the same period in 2015. The decrease in adjusted operating income was largely due to a decrease in volumes gathered, resulting from lower production volumes in the Fayetteville Shale.
First Six Months of 2016 Financial Results
For the first six months of 2016, Southwestern reported a net loss attributable to common stock of $1.8 billion, or $4.63 per diluted share, and an adjusted net loss attributable to common stock (reconciled below) of $66 million, or $0.17 per diluted share. This compares to a net loss attributable to common stock of $762 million, or $2.01 per diluted share, and an adjusted net income attributable to common stock of $74 million, or $0.20 per diluted share, in the first six months of 2015.
Net cash provided by operating activities was $165 million for the first six months of 2016, compared to $940 million in the first six months of 2015. Net cash flow (reconciled below) was $261 million for the first six months of 2016, compared to $832 million for the same period in 2015.
The first six months of 2015 included the operating results from the gathering system in northeast Pennsylvania and conventional E&P assets in East Texas and the Arkoma basin that were divested during the second quarter of 2015.
E&P Segment – The operating loss from the Company's E&P segment was $1.7 billion for the first six months of 2016, compared to an operating loss of $1.6 billion during the first six months of 2015. The larger operating loss was primarily due to lower realized commodity prices. The adjusted operating loss from the Company's E&P segment was $133 million for the first six months of 2016 (reconciled below), when excluding the non-cash impairment and restructuring charges, compared to an adjusted operating loss of $26 million for the same period in 2015. The larger loss was primarily due to lower realized natural gas prices along with decreases in realized oil and NGL prices partially offset by lower operating costs.
Net production totaled 462 Bcfe in the first six months of 2016, down less than anticipated from the 478 Bcfe in the first six months of 2015. The first six months of 2016 included 199 Bcf from the Fayetteville Shale, 184 Bcf from Northeast Appalachia and 78 Bcfe from Southwest Appalachia. This compares to 236 Bcf from the Fayetteville Shale, 170 Bcf from Northeast Appalachia and 65 Bcfe from Southwest Appalachia in the first six months of 2015.
Due to the continued challenging commodity price environment, including the effect of derivatives, Southwestern's average realized gas price in the first six months of 2016 was $1.40 per Mcf, down from $2.60 per Mcf in the six months of 2015. The Company's commodity derivative activities increased its average realized gas price by $0.07 per Mcf during the first six months of 2016, compared to an increase of $0.41 per Mcf during the same period in 2015. Disregarding the impact of derivatives, the Company's average price received for its gas production during the first six months of 2016 was approximately $0.69 per Mcf lower than average NYMEX settlement prices, compared to approximately $0.62 per Mcf lower than average NYMEX settlement prices during the first six months of 2015.
Lease operating expenses per unit of production for the Company's E&P segment declined to $0.88 per Mcfe in the first six months of 2016, compared to $0.93 per Mcfe in the first six months of 2015. The decrease was primarily due to reduced workover activity and contract services as well as the successful renegotiation of the existing gathering and processing rates in Southwest Appalachia.
General and administrative expenses per unit of production decreased to $0.20 per Mcfe in the first six months of 2016, compared to $0.22 per Mcfe in the first six months quarter of 2015, down primarily due to a decrease in employee costs. This excludes the restructuring charges associated with the workforce reduction, which were $69 million for the E&P segment in the first six months of 2016.
Taxes other than income taxes were down to $0.09 per Mcfe in the first six months of 2016, compared to $0.11 per Mcfe in the first six months of 2015. This excludes the restructuring charges associated with the workforce reduction, which were $3 million for the E&P segment in the first six months of 2016.
The Company's full cost pool amortization rate declined significantly to $0.42 per Mcfe in the first six months of 2016, compared to $1.14 per Mcfe in the first six months of 2015.
Midstream – Operating income for the Company's Midstream segment was $117 million for the first six months of 2016, compared to $443 million for the same period in 2015. The decrease in operating income was primarily due to 2015 including a $278 million gain on sale of assets divested. Adjusted operating income (reconciled below) for the Company's Midstream segment was $120 million for the first six months of 2016, excluding the impacts from restructuring charges. This is down from $165 million for the same period in 2015, which excluded a $278 million gain on sale of assets divested. The decrease in adjusted operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale and the sale of the Company's northeast Pennsylvania gathering assets.
Capital Structure and Investments – At June 30, 2016, the Company had total debt of approximately $5.8 billion and $4.8 billion in net debt (a non-GAAP measure reconciled below). These amounts do not reflect the effect of the $1.25 billion equity offering and retirement of approximately $700 million of 2018 bonds through tender offers, all completed in July, or the anticipated closing of the previously announced asset sale in the third quarter.
In June 2016, the Company entered into a new credit agreement for $1,934 million, consisting of a $1,191 million secured term loan that is fully drawn and a new $743 million unsecured revolving credit facility, which matures in December 2020, and reduced its existing $2.0 billion unsecured revolving credit facility due in December 2018 to $66 million. As of June 30, 2016, there were no borrowings under either revolving credit facility; however, there was $169 million in letters of credit outstanding against the new revolving credit facility.
During the first six months of 2016, Southwestern invested a total of $196 million. This is down from $1.6 billion in the first six months of 2015. The $196 million includes approximately $193 million invested in its E&P business, $2 million invested in its Midstream segment and $1 million invested for corporate and other purposes. Of the $196 million, approximately $82 million was associated with capitalized interest and $41 million was associated with capitalized expenses.
Revised 2016 Guidance
The Company has increased its production guidance by 45 Bcfe (using midpoints) for 2016 based on the strong performance of the portfolio for the first six months and, to a lesser extent, improved commodity prices and the availability of capital from the Company's July equity offering. The revised total natural gas, NGL and oil production guidance for 2016 is raised to 865 to 875 Bcfe, an increase of approximately 5% over the Company's previous 2016 production guidance.
Of the 45 Bcfe increase (using midpoints), approximately 33 Bcfe is a result of the strong portfolio performance and only 12 Bcfe is associated with the increased capital being invested during the second half of the year. While having only an estimated 12 Bcfe impact on 2016 production, the increased capital investments for the year will have a significant impact on 2017 production. Of the Company's total expected production in 2016, approximately 371 to 374 Bcf is expected to come from the Fayetteville Shale, approximately 345 to 348 Bcf is expected to come from Northeast Appalachia and 147 to 151 Bcfe is expected to come from Southwest Appalachia.
The Company is currently in the process of reinitiating drilling and completion activity in each of its operating areas and plans to make incremental capital investments of up to $500 million from its July equity offering, with approximately $375 million of this incremental capital expected to be invested before the end of 2016. As part of this plan, the Company reinitiated drilling with its first rig this week in Northeast Appalachia and intends to increase its company-wide rig count to five by the end of the third quarter. These five rigs are expected to be comprised of two in Northeast Appalachia, two in Southwest Appalachia and one in Fayetteville. Additionally, the Company expects to complete approximately 90 to 100 wells in the second half of 2016, which includes new wells drilled and a portion of the inventory of previously drilled but uncompleted wells. The Company's updated guidance for 2016 is shown below.
2016 Guidance | |||
Original |
Revised | ||
$ millions (except production and well count) |
$2.35 / $35.00 |
$2.45 / $45.00 | |
Capital: |
|||
Discretionary Capital |
$100 - $125 |
$485 - $525 | |
Capitalized Interest and Expenses |
$250 - $275 |
$240 - $250 | |
Total Capital |
$350 - $400 |
$725 - $775 | |
Net Cash Flow (1) (2) |
$450 - $500 |
$655 - $680 | |
Adjusted net income (loss) attributable to common stock (1) (2) |
($180) - ($160) |
($10) - $10 | |
Adjusted EBITDA (1) (2) |
$450 - $500 |
$675 - $700 | |
Production (Bcfe) |
815 - 835 |
865 - 875 | |
Wells Drilled |
- |
55 - 65 | |
Wells Completed |
20 - 30 |
100 - 110 | |
Wells Placed on Production |
20 - 30 |
120 - 130 | |
Ending DUC Inventory |
100 - 110 |
55 - 65 |
(1) |
Excludes the impact of one-time severance charges associated with the 2016 workforce reduction. | |
(2) |
This represents a Non-GAAP measure; see "Explanation and Reconciliation of Non-GAAP Financial Measures" below. |
Estimated Capital Investments in 2016 | |||
Capital Investments | |||
YTD |
Total Year | ||
$ millions |
June 2016 |
2016 (1) | |
Northeast Appalachia |
$ 24 |
$ 220 | |
Southwest Appalachia |
20 |
175 | |
Fayetteville Shale |
13 |
80 | |
Midstream Services |
1 |
5 | |
Capitalized Interest |
82 |
160 | |
Capitalized G&A |
41 |
85 | |
E&P Services & Corporate |
15 |
25 | |
Total Capital Investments |
$ 196 |
$ 750 |
(1) Assumes midpoint of total company guidance provided in table above. |
Estimated Production by Quarter in 2016 | ||||||||||
1st Quarter |
2nd Quarter |
3rd Quarter |
4th Quarter |
Total Year 2016 | ||||||
Previous Guidance (Bcfe) |
230 - 235 |
210 - 215 |
195 - 200 |
180 - 185 |
815 - 835 | |||||
New Guidance: |
||||||||||
Natural Gas (Bcf) |
213 |
203 |
186 - 190 |
179 - 184 |
781 - 790 | |||||
Oil (MBbls) |
607 |
586 |
510 - 560 |
470 - 510 |
2,173 - 2,263 | |||||
NGLs (MBbls) |
3,376 |
3,136 |
2,750 - 2,850 |
2,550 - 2,650 |
11,812 - 12,012 | |||||
Total Production (Bcfe) |
237 |
225 |
206 - 211 |
197 - 202 |
865 - 875 |
Estimated E&P Pricing Deductions in 2016 |
||
Avg Gas Basis Differential and Transportation Charge |
$0.73 - $0.83 per Mcf | |
Avg Oil Basis Differential and Transportation Charge |
$13.00 - $15.00 per Bbl | |
Avg NGL Price Realization |
15% - 20% of WTI | |
Estimated E&P Operating Expenses in 2016 (per Mcfe) |
||
Lease Operating Expenses |
$0.88 - $0.92 | |
General & Administrative Expense |
$0.22 - $0.25 | |
Taxes, Other Than Income Taxes |
$0.09 - $0.11 | |
Other Items in 2016 |
||
Midstream EBITDA ($ in millions) |
$255 - $270 | |
Net Interest Expense ($ in millions) |
$60 - $65 |
E&P Operations Review
During the first six months of 2016, Southwestern invested approximately $193 million in its E&P business, including $71 million in investment capital and $122 in capitalized interest and expenses.
In Northeast Appalachia, the Company placed 6 wells on production in the second quarter of 2016. This activity resulted in net gas production of 90 Bcf, up 4% from 87 Bcf in the second quarter of 2015. Gross operated production in Northeast Appalachia was approximately 1.2 Bcf per day at June 30, 2016. The Company expects to drill 37 to 40 wells, complete 35 to 38 wells and place an additional 29 to 33 wells on production in the second half of 2016 in this operating area.
In Southwest Appalachia, net production of 38 Bcfe in the second quarter of 2016 was 8% higher than the 35 Bcfe of net production in the same period of 2015. The gross operated production rate in Southwest Appalachia was approximately 644 MMcfe per day at June 30, 2016. The Company placed 11 new wells on production in the second quarter of 2016 and expects to drill 11 to 15 wells, complete 20 to 24 wells and place an additional 19 to 22 wells on production in the second half of 2016 in this operating area.
In the second quarter of 2016, Southwestern's net gas production from the Fayetteville Shale was 96 Bcf, compared to 121 Bcf in the second quarter of 2015. Gross operated gas production in the Fayetteville Shale was approximately 1.5 Bcf per day at June 30, 2016. The Company placed 6 wells on production in the second quarter of 2016 and expects to drill 7 to 10 wells, complete 36 to 39 wells and place an additional 37 to 40 wells on production in the second half of 2016 in this operating area.
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods.
One such non-GAAP financial measure is net cash flow. Management presents this measure because (i) it is accepted as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt, (ii) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the Company may not control and (iii) changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.
Additional non-GAAP financial measures the Company may present from time to time are net debt, adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's position and performance are measured relative to the position and performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures as of and for the three and six months ended June 30, 2016 and June 30, 2015 and the 2016 Guidance, as applicable. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net loss attributable to common stock: |
|||||
Net loss attributable to common stock |
$ |
(620) |
$ |
(815) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
470 |
1,535 | |||
Restructuring charges |
11 |
– | |||
Gain on sale of assets, net |
(2) |
(277) | |||
Transaction costs |
– |
1 | |||
Loss on certain derivatives |
108 |
50 | |||
Adjustments due to inventory valuation |
1 |
– | |||
Adjustments due to discrete tax items(1) |
216 |
– | |||
Tax impact on adjustments |
(218) |
(503) | |||
Adjusted net loss attributable to common stock |
$ |
(34) |
$ |
(9) | |
3 Months Ended June 30, | |||||
2016 |
2015 | ||||
Diluted earnings per share: |
|||||
Diluted earnings per share(2) |
$ |
(1.61) |
$ |
(2.13) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
1.22 |
4.02 | |||
Restructuring charges |
0.03 |
– | |||
Gain on sale of assets, net |
(0.01) |
(0.72) | |||
Transaction costs |
– |
0.00 | |||
Loss on certain derivatives |
0.28 |
0.13 | |||
Adjustments due to inventory valuation |
0.00 |
– | |||
Adjustments due to discrete tax items(1) |
0.56 |
– | |||
Tax impact on adjustments |
(0.56) |
(1.32) | |||
Adjusted diluted earnings per share |
$ |
(0.09) |
$ |
(0.02) | |
(1) |
2016 primarily relates to the exclusion of certain discrete tax adjustments in the second quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0% before the impacts of any valuation allowance. | ||
(2) |
Does not include the effect of 98.9 million shares of common stock issued in July 2016. |
6 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net loss attributable to common stock |
$ |
(1,779) |
$ |
(762) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
– |
(13) | |||
Impairment of natural gas and oil properties |
1,504 |
1,535 | |||
Restructuring charges |
75 |
– | |||
Gain on sale of assets, net |
(2) |
(277) | |||
Transaction costs |
– |
52 | |||
Loss on certain derivatives |
129 |
71 | |||
Adjustments due to inventory valuation |
4 |
– | |||
Adjustments due to discrete tax items(1) |
647 |
– | |||
Tax impact on adjustments |
(644) |
(532) | |||
Adjusted net income (loss) attributable to common stock |
$ |
(66) |
$ |
74 | |
6 Months Ended June 30, | |||||
2016 |
2015 | ||||
Diluted earnings per share: |
|||||
Diluted earnings per share(2) |
$ |
(4.63) |
$ |
(2.01) | |
Add back: |
|||||
Participating securities – mandatory convertible preferred stock |
– |
(0.03) | |||
Impairment of natural gas and oil properties |
3.91 |
4.05 | |||
Restructuring charges |
0.19 |
– | |||
Gain on sale of assets, net |
(0.00) |
(0.73) | |||
Transaction costs |
– |
0.14 | |||
Loss on certain derivatives |
0.34 |
0.19 | |||
Adjustments due to inventory valuation |
0.01 |
– | |||
Adjustments due to discrete tax items(1) |
1.68 |
– | |||
Tax impact on adjustments |
(1.67) |
(1.41) | |||
Adjusted diluted earnings per share |
$ |
(0.17) |
$ |
0.20 | |
(1) |
2016 primarily relates to the exclusion of certain discrete tax adjustments in the first six months of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0% before the impacts of any valuation allowance. |
(2) |
Does not include the effect of 98.9 million shares of common stock issued in July 2016. |
3 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
73 |
$ |
399 | |
Add back: |
|||||
Changes in operating assets and liabilities |
17 |
(60) | |||
Restructuring charges |
24 |
– | |||
Net Cash Flow |
$ |
114 |
$ |
339 | |
6 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
165 |
$ |
940 | |
Add back: |
|||||
Changes in operating assets and liabilities |
50 |
(108) | |||
Restructuring charges |
46 |
– | |||
Net Cash Flow |
$ |
261 |
$ |
832 | |
3 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
E&P segment operating loss: |
|||||
E&P segment operating loss |
$ |
(549) |
$ |
(1,639) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
470 |
1,535 | |||
Restructuring charges |
11 |
– | |||
Adjusted E&P segment operating loss |
$ |
(68) |
$ |
(104) | |
6 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
E&P segment operating loss: |
|||||
E&P segment operating loss |
$ |
(1,709) |
$ |
(1,561) | |
Add back: |
|||||
Impairment of natural gas and oil properties |
1,504 |
1,535 | |||
Restructuring charges |
72 |
– | |||
Adjusted E&P segment operating loss |
$ |
(133) |
$ |
(26) | |
3 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Midstream segment operating income: |
|||||
Midstream segment operating income |
$ |
57 |
$ |
355 | |
Add back: |
|||||
Gain on sale of assets, net |
– |
(278) | |||
Adjusted Midstream segment operating income |
$ |
57 |
$ |
77 | |
6 Months Ended June 30, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Midstream segment operating income: |
|||||
Midstream segment operating income |
$ |
117 |
$ |
443 | |
Add back: |
|||||
Restructuring charges |
3 |
– | |||
Gain on sale of assets, net |
– |
(278) | |||
Adjusted Midstream segment operating income |
$ |
120 |
$ |
165 |
June 30, |
December 31, | ||||
2016 |
2015 | ||||
(in millions) | |||||
Net debt: |
|||||
Total debt |
$ |
5,768 |
$ |
4,705 | |
Subtract: |
|||||
Cash and cash equivalents |
(998) |
(15) | |||
Net debt |
$ |
4,770 |
$ |
4,690 |
2016 Guidance | ||||
Original |
Revised | |||
$2.35 Gas / $35 Oil |
$2.45 Gas / $45 Oil | |||
($ millions) | ||||
Cash flow from operating activities: |
||||
Net cash provided by operating activities |
$405 - $450 |
$609 - $634 | ||
Add back (deduct): |
||||
One-time cash severance payments |
45 - 50 |
46 | ||
Change in operating assets and liabilities |
– |
– | ||
Net cash flow |
$450 - $500 |
$655 - $680 | ||
2016 Guidance | ||||
Original |
Revised | |||
$2.35 Gas / $35 Oil |
$2.45 Gas / $45 Oil | |||
($ millions) | ||||
Net loss attributable to common stock |
($223) - ($197) |
($1,655) - ($1,625) | ||
Add back (deduct): |
||||
Impairment of natural gas and oil properties |
– |
1,504 | ||
Restructuring charges |
60 - 70 |
75 | ||
Gain on sale of assets, net |
– |
(2) | ||
Loss on certain derivatives |
– |
129 | ||
Adjustments due to inventory valuation |
– |
4 | ||
Adjustments due to discrete tax items |
– |
568 - 579 | ||
Tax impact on adjustments |
(23) - (27) |
(644) | ||
Adjusted net income (loss) attributable to common stock |
($180) - ($160) |
($10) - $10 | ||
(1) |
Does not include any forecasted impairments. |
2016 Guidance | ||||
Original |
Revised | |||
$2.35 Gas / $35 Oil |
$2.45 Gas / $45 Oil | |||
($ in millions) | ||||
Net loss attributable to common stock |
($223) - ($197) |
($1,655) - ($1,625) | ||
Add back: |
||||
Mandatory convertible preferred stock dividend |
108 - 108 |
108 - 108 | ||
Net loss attributable to SWN |
($115) - ($89) |
($1,547) - ($1,517) | ||
Add back: |
||||
Provision for income taxes |
(70) - (54) |
– | ||
Impairment of natural gas and oil properties |
– |
1,504 | ||
Depreciation, depletion and amortization |
520 - 530 |
440 - 450 | ||
Gain on sale of assets |
– |
(2) | ||
Loss on certain derivatives |
– |
129 | ||
Interest expense |
53 - 58 |
60 - 65 | ||
Write-down on inventory |
– |
4 | ||
Restructuring costs |
60 - 70 |
75 | ||
Adjusted EBITDA |
$450 - $500 |
$675 - 700 |
(1) |
Does not include any forecasted impairments. |
Southwestern management will host a teleconference call on Friday, July 22, 2016 at 10:00 a.m. Eastern to discuss its second quarter 2016 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
OPERATING STATISTICS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the six months ended | |||||||||||
June 30, |
June 30, | |||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
Exploration & Production |
||||||||||||
Production |
||||||||||||
Gas production (Bcf) |
203 |
226 |
416 |
445 | ||||||||
Oil production (MBbls) |
586 |
589 |
1,193 |
1,134 | ||||||||
NGL production (MBbls) |
3,136 |
2,574 |
6,512 |
4,340 | ||||||||
Total production (Bcfe) |
225 |
245 |
462 |
478 | ||||||||
Commodity Prices |
||||||||||||
Average realized gas price per Mcf, including derivatives |
$ |
1.32 |
$ |
2.23 |
$ |
1.40 |
$ |
2.60 | ||||
Average realized gas price per Mcf, excluding derivatives |
$ |
1.21 |
$ |
1.76 |
$ |
1.33 |
$ |
2.19 | ||||
Average realized oil price per Bbl |
$ |
32.46 |
$ |
40.88 |
$ |
25.43 |
$ |
36.08 | ||||
Average realized NGL price per Bbl |
$ |
6.41 |
$ |
5.77 |
$ |
5.67 |
$ |
7.63 | ||||
Summary of Derivative Activity in the Statement of Operations |
||||||||||||
Settled commodity amounts included in "Operating Revenues" (in millions) |
$ |
– |
$ |
53 |
$ |
– |
$ |
95 | ||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
23 |
$ |
52 |
$ |
31 |
$ |
88 | ||||
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(108) |
$ |
(52) |
$ |
(126) |
$ |
(70) | ||||
Average unit costs per Mcfe |
||||||||||||
Lease operating expenses |
$ |
0.87 |
$ |
0.93 |
$ |
0.88 |
$ |
0.93 | ||||
General & administrative expenses (1) |
$ |
0.21 |
$ |
0.21 |
$ |
0.20 |
$ |
0.22 | ||||
Taxes, other than income taxes (2) |
$ |
0.09 |
$ |
0.10 |
$ |
0.09 |
$ |
0.11 | ||||
Full cost pool amortization |
$ |
0.35 |
$ |
1.13 |
$ |
0.42 |
$ |
1.14 | ||||
Midstream |
||||||||||||
Volumes marketed (Bcfe) |
271 |
289 |
550 |
549 | ||||||||
Volumes gathered (Bcf) |
154 |
201 |
318 |
434 |
(1) |
Excludes $11 million and $69 million of restructuring charges for the three and six months ended June 30, 2016, respectively. |
(2) |
Excludes $3 million of restructuring charges for the six months ended June 30, 2016, respectively. |
STATEMENTS OF OPERATIONS (Unaudited) |
||||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the six months ended | |||||||||||
June 30, |
June 30, | |||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
(in millions, except share/per share amounts) | ||||||||||||
Operating Revenues |
||||||||||||
Gas sales |
$ |
251 |
$ |
457 |
$ |
566 |
$ |
1,082 | ||||
Oil sales |
20 |
24 |
31 |
41 | ||||||||
NGL sales |
20 |
15 |
37 |
33 | ||||||||
Marketing |
196 |
222 |
394 |
447 | ||||||||
Gas gathering |
35 |
46 |
73 |
94 | ||||||||
522 |
764 |
1,101 |
1,697 | |||||||||
Operating Costs and Expenses |
||||||||||||
Marketing purchases |
197 |
219 |
393 |
441 | ||||||||
Operating expenses |
151 |
176 |
316 |
331 | ||||||||
General and administrative expenses |
56 |
60 |
110 |
128 | ||||||||
Restructuring charges |
11 |
– |
75 |
– | ||||||||
Depreciation, depletion and amortization |
107 |
308 |
250 |
601 | ||||||||
Impairment of natural gas and oil properties |
470 |
1,535 |
1,504 |
1,535 | ||||||||
Gain on sale of assets, net |
– |
(277) |
– |
(277) | ||||||||
Taxes, other than income taxes |
22 |
27 |
45 |
57 | ||||||||
1,014 |
2,048 |
2,693 |
2,816 | |||||||||
Operating Loss |
(492) |
(1,284) |
(1,592) |
(1,119) | ||||||||
Interest Expense |
||||||||||||
Interest on debt |
56 |
52 |
109 |
102 | ||||||||
Other interest charges |
2 |
3 |
4 |
52 | ||||||||
Interest capitalized |
(41) |
(54) |
(82) |
(102) | ||||||||
17 |
1 |
31 |
52 | |||||||||
Other Income (Loss), Net |
– |
3 |
(3) |
2 | ||||||||
Gain (Loss) on Derivatives |
(85) |
1 |
(99) |
15 | ||||||||
Loss Before Income Taxes |
(594) |
(1,281) |
(1,725) |
(1,154) | ||||||||
Provision (Benefit) for Income Taxes |
||||||||||||
Current |
– |
7 |
– |
7 | ||||||||
Deferred |
(1) |
(500) |
– |
(451) | ||||||||
(1) |
(493) |
– |
(444) | |||||||||
Net Loss |
(593) |
(788) |
(1,725) |
(710) | ||||||||
Mandatory convertible preferred stock dividend |
27 |
27 |
54 |
52 | ||||||||
Net Loss Attributable to Common Stock |
$ |
(620) |
$ |
(815) |
$ |
(1,779) |
$ |
(762) | ||||
Loss Per Common Share |
||||||||||||
Basic |
$ |
(1.61) |
$ |
(2.13) |
$ |
(4.63) |
$ |
(2.01) | ||||
Diluted |
$ |
(1.61) |
$ |
(2.13) |
$ |
(4.63) |
$ |
(2.01) | ||||
Weighted Average Common Shares Outstanding | ||||||||||||
Basic |
385,594,815 |
382,114,011 |
384,232,831 |
378,797,446 | ||||||||
Diluted |
385,594,815 |
382,114,011 |
384,232,831 |
378,797,446 |
BALANCE SHEETS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
June 30, |
December 31, | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,278 |
$ |
393 | ||
Property and equipment |
24,529 |
24,364 | ||||
Less: Accumulated depreciation, depletion and amortization |
(18,582) |
(16,821) | ||||
Total property and equipment, net |
5,947 |
7,543 | ||||
Other long-term assets |
152 |
150 | ||||
Total assets |
7,377 |
8,086 | ||||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
591 |
707 | ||||
Long-term debt |
5,767 |
4,704 | ||||
Pension and other postretirement liabilities |
51 |
50 | ||||
Other long-term liabilities |
395 |
343 | ||||
Total liabilities |
6,804 |
5,804 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 392,496,825 (1) shares as of June 30, 2016 (does not include 2,100,119 shares declared as a stock dividend on June 14, 2016 and issued on July 15, 2016) and 390,138,549 as of December 31, 2015 |
4 |
4 | ||||
Preferred stock, $0.01 par value,10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of June 30, 2016 and December 31, 2015, conversion in January 2018 |
– |
– | ||||
Additional paid-in capital |
3,418 |
3,409 | ||||
Accumulated deficit |
(2,807) |
(1,082) | ||||
Accumulated other comprehensive loss |
(41) |
(48) | ||||
Common stock in treasury; 31,269 shares as of June 30, 2016 and 47,149 as of December 31, 2015, respectively |
(1) |
(1) | ||||
Total equity |
573 |
2,282 | ||||
Total liabilities and equity |
$ |
7,377 |
$ |
8,086 |
(1) |
Does not include 98,900,000 shares of common stock issued in July 2016. |
STATEMENTS OF CASH FLOWS (Unaudited) |
||||||
Southwestern Energy Company and Subsidiaries |
||||||
For the six months ended | ||||||
June 30, | ||||||
2016 |
2015 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities |
||||||
Net loss |
$ |
(1,725) |
$ |
(710) | ||
Adjustments to reconcile net loss to net cash provided by operating |
||||||
Depreciation, depletion and amortization |
250 |
603 | ||||
Impairment of natural gas and oil properties |
1,504 |
1,535 | ||||
Amortization of debt issuance costs |
4 |
49 | ||||
Deferred income taxes |
– |
(451) | ||||
Loss on derivatives, net of settlement |
129 |
71 | ||||
Stock-based compensation |
17 |
12 | ||||
Gain on sales of assets, net |
– |
(277) | ||||
Restructuring charges |
29 |
– | ||||
Other |
7 |
– | ||||
Change in assets and liabilities |
(50) |
108 | ||||
Net cash provided by operating activities |
165 |
940 | ||||
Cash Flows From Investing Activities |
||||||
Capital investments |
(241) |
(974) | ||||
Acquisitions |
– |
(569) | ||||
Proceeds from sale of property and equipment |
54 |
703 | ||||
Other |
1 |
10 | ||||
Net cash used in investing activities |
(186) |
(830) | ||||
Cash Flows From Financing Activities |
||||||
Payments on current portion of long-term debt |
(1) |
(1) | ||||
Payments on long-term debt |
– |
(500) | ||||
Payments on short-term debt |
– |
(4,500) | ||||
Payments on revolving credit facility |
(3,268) |
(1,534) | ||||
Borrowings under revolving credit facility |
3,152 |
1,804 | ||||
Payments on commercial paper |
(242) |
(1,182) | ||||
Borrowings under commercial paper |
242 |
1,288 | ||||
Change in bank drafts outstanding |
(21) |
(1) | ||||
Proceeds from issuance of long-term debt |
1,191 |
2,200 | ||||
Debt issuance costs |
(16) |
(17) | ||||
Proceeds from issuance of common stock |
– |
669 | ||||
Proceeds from issuance of mandatory convertible preferred stock |
– |
1,673 | ||||
Preferred stock dividend |
(27) |
(25) | ||||
Other |
(6) |
– | ||||
Net cash provided by (used in) financing activities |
1,004 |
(126) | ||||
Increase (decrease) in cash and cash equivalents |
983 |
(16) | ||||
Cash and cash equivalents at beginning of year |
15 |
53 | ||||
Cash and cash equivalents at end of period |
$ |
998 |
$ |
37 |
SEGMENT INFORMATION (Unaudited) |
|||||||||||||||
Southwestern Energy Company and Subsidiaries |
Exploration |
||||||||||||||
and |
|||||||||||||||
Production |
Midstream |
Other |
Eliminations |
Total | |||||||||||
(in millions) | |||||||||||||||
Three months ended June 30, 2016 |
|||||||||||||||
Revenues |
$ |
284 |
$ |
559 |
$ |
– |
$ |
(321) |
$ |
522 | |||||
Marketing purchases |
– |
452 |
– |
(255) |
197 | ||||||||||
Operating expenses |
196 |
21 |
– |
(66) |
151 | ||||||||||
General and administrative expenses |
46 |
10 |
– |
– |
56 | ||||||||||
Restructuring charges |
11 |
– |
– |
– |
11 | ||||||||||
Depreciation, depletion and amortization |
90 |
17 |
– |
– |
107 | ||||||||||
Impairment of natural gas and oil properties |
470 |
– |
– |
– |
470 | ||||||||||
Taxes, other than income taxes |
20 |
2 |
– |
– |
22 | ||||||||||
Operating income (loss) |
(549) |
57 |
– |
– |
(492) | ||||||||||
Capital investments(1) |
73 |
– |
1 |
– |
74 | ||||||||||
Three months ended June 30, 2015 |
|||||||||||||||
Revenues |
$ |
490 |
$ |
766 |
$ |
– |
$ |
(492) |
$ |
764 | |||||
Marketing purchases |
– |
624 |
– |
(405) |
219 | ||||||||||
Operating expenses |
226 |
35 |
2 |
(87) |
176 | ||||||||||
General and administrative expenses |
52 |
9 |
(1) |
– |
60 | ||||||||||
Depreciation, depletion and amortization |
291 |
17 |
– |
– |
308 | ||||||||||
Impairment of natural gas and oil properties |
1,535 |
– |
– |
– |
1,535 | ||||||||||
(Gain) loss on sale of assets, net |
1 |
(278) |
– |
– |
(277) | ||||||||||
Taxes, other than income taxes |
24 |
4 |
(1) |
– |
27 | ||||||||||
Operating income (loss) |
(1,639) |
355 |
– |
– |
(1,284) | ||||||||||
Capital investments(1) |
389 |
19 |
7 |
– |
415 | ||||||||||
Six months ended June 30, 2016 |
|||||||||||||||
Revenues |
$ |
620 |
$ |
1,180 |
$ |
– |
$ |
(699) |
$ |
1,101 | |||||
Marketing purchases |
– |
955 |
– |
(562) |
393 | ||||||||||
Operating expenses |
405 |
48 |
– |
(137) |
316 | ||||||||||
General and administrative expenses |
91 |
19 |
– |
– |
110 | ||||||||||
Restructuring charges |
72 |
3 |
– |
– |
75 | ||||||||||
Depreciation, depletion and amortization |
217 |
33 |
– |
– |
250 | ||||||||||
Impairment of natural gas and oil properties |
1,504 |
– |
– |
– |
1,504 | ||||||||||
Taxes, other than income taxes |
40 |
5 |
– |
– |
45 | ||||||||||
Operating income (loss) |
(1,709) |
117 |
– |
– |
(1,592) | ||||||||||
Capital investments(1) |
193 |
2 |
1 |
– |
196 | ||||||||||
Six months ended June 30, 2015 |
|||||||||||||||
Revenues |
$ |
1,145 |
$ |
1,704 |
$ |
1 |
$ |
(1,153) |
$ |
1,697 | |||||
Marketing purchases |
– |
1,410 |
– |
(969) |
441 | ||||||||||
Operating expenses |
442 |
71 |
2 |
(184) |
331 | ||||||||||
General and administrative expenses |
108 |
20 |
– |
– |
128 | ||||||||||
Depreciation, depletion and amortization |
569 |
32 |
– |
– |
601 | ||||||||||
Impairment of natural gas and oil properties |
1,535 |
– |
– |
– |
1,535 | ||||||||||
(Gain) loss on sale of assets, net |
1 |
(278) |
– |
– |
(277) | ||||||||||
Taxes, other than income taxes |
51 |
6 |
– |
– |
57 | ||||||||||
Operating income (loss) |
(1,561) |
443 |
(1) |
– |
(1,119) | ||||||||||
Capital investments(1) |
1,419 |
157 |
10 |
– |
1,586 |
(1) |
Capital investments includes a $27 million increase and an $11 million decrease for the three months ended June 30, 2016 and 2015, respectively, and a $51 million decrease and an $11 million decrease for the six months ended June 30, 2016 and 2015, respectively, relating to the change in accrued expenditures between periods. E&P capital for the three months ended June 30, 2015 includes approximately $516 million related to the WPX Property and Statoil Property Acquisitions. Midstream capital for the six months ended June 30, 2015 includes approximately $119 million of firm transport associated with the WPX Property Acquisition. |
SOURCE Southwestern Energy Company
HOUSTON, July 20, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced early results of the previously announced cash tender offers (the "Tender Offers") to purchase its outstanding senior notes listed in the table below (collectively, the "Notes") for a maximum aggregate purchase price (excluding accrued interest) of up to $750.0 million (the "Aggregate Maximum Purchase Price").
According to information received from D.F. King & Co., Inc. ("D.F. King"), the Tender Agent and Information Agent for the Tender Offers, as of 5:00 p.m., New York City time, on July 19, 2016 (that date and time, the "Early Tender Time"), the Company had received valid tenders from holders of the Notes as outlined in the table below.
Title of Security |
CUSIP Number |
Aggregate Principal Amount Outstanding (U.S. $) |
Principal Amount Tendered |
Principal Amount Accepted |
Acceptance Priority Level |
Total Consideration per U.S. $1,000 Principal Amount of Notes (1) |
3.30% Senior Notes due 2018 |
845467AJ8 |
$350,000,000 |
$312,009,000 |
$312,009,000 |
1 |
$1,050.00 |
7.50% Senior Notes due 2018 |
845467AE9 |
$600,000,000 |
$484,032,000 |
$388,405,000 |
2 |
$1,087.50 |
4.05% Senior Notes due 2020 |
845467AK5 |
$850,000,000 |
$262,092,000 |
None |
3 |
$1,000.00 |
______________________________________
|
(1) Includes the Early Tender Premium (as defined below) but excludes accrued and unpaid interest. |
Subject to the satisfaction or waiver of all remaining conditions to the Tender Offers described in the Company's Offer to Purchase, dated June 29, 2016 (as amended on July 14, 2016 and July 15, 2016, the "Offer to Purchase") having been either satisfied or waived by the Company, the Company intends to accept for purchase all of the 3.30% Senior Notes due 2018 (the "3.30% 2018 Notes") and a prorated amount of the 7.50% Senior Notes due 2018 (the "7.50% 2018 Notes" and, together with the 3.30% 2018 Notes, the "2018 Notes") validly tendered (and not validly withdrawn) before the Early Tender Time, such that the aggregate purchase price for the 2018 Notes equals the Aggregate Maximum Purchase Price. These Notes will be purchased on the "Early Settlement Date," which is currently expected to occur on the date hereof.
Because the Tender Offers have been fully subscribed as of the Early Tender Time, holders who tender Notes after the Early Tender Time will not have any of their Notes accepted for purchase. Any Notes tendered after the Early Tender Time, together with certain of the 7.50% 2018 Notes and all of the 4.05% Senior Notes due 2020 tendered prior to the Early Tender Time, will be returned to the holders as described in the Offer to Purchase.
Payments for 2018 Notes purchased will include accrued and unpaid interest from and including the last interest payment date applicable to the relevant series of Notes up to, but not including, the applicable Settlement Date (as such term is defined in the Offer to Purchase). Holders of 2018 Notes that were validly tendered (and not validly withdrawn) prior to the Early Tender Time and accepted for purchase pursuant to the Tender Offers will receive the applicable Total Consideration (as set forth in the table above) for such series, which includes the early tender premium of $30.00 for each series of Notes as set forth in the Offer to Purchase.
As previously announced, the financing condition to which the Tender Offers were subject has been satisfied. The Tender Offers are subject to the remaining conditions described in the Offer to Purchase. Full details of the terms and conditions of the Tender Offers are set forth in the Offer to Purchase, which is available from D.F. King.
Credit Suisse Securities (USA) LLC ("Credit Suisse") and Mitsubishi UFJ Securities (USA), Inc. ("MUFG") are the Lead Dealer Managers in the Tender Offers. Persons with questions regarding the Amended Tender Offers should contact Credit Suisse at (toll free) (800) 820-1653 or (collect) (212) 538-2147 or MUFG at (toll free) (877) 744-4532 or (collect) (212) 405-7481. Requests for the Offer to Purchase should be directed to D.F. King at (toll free) (866) 406-2283 or (collect) (212) 269-5550 or SWN@dfking.com.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Tender Offers are being made only pursuant to the Offer to Purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers will be deemed to be made on behalf of the Company by the Dealer Managers, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, July 15, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced additional amendments with respect to its previously announced cash tender offers to purchase (as amended, the "Amended Tender Offers") its outstanding senior notes listed in the table below (collectively, the "Notes") for a maximum aggregate purchase price (excluding accrued interest) of up to $750.0 million (the "Aggregate Maximum Purchase Price").
The amendments provide for:
This announcement amends the Company's Offer to Purchase, dated June 29, 2016 (the "Offer to Purchase"). Other than the amendments described above, all terms and conditions in the Offer to Purchase remain unchanged.
Aggregate Principal Amount (U.S. $) |
Dollars per U.S. $1,000 Principal Amount of Notes | |||||||
Title of Notes |
CUSIP Number |
Sub-Cap (U.S. $) |
Acceptance |
Aggregate Principal Amount Tendered as of (U.S. $) |
Amended Tender |
Early Tender |
Amended Total | |
3.30% Senior Notes due 2018 |
845467AJ8 |
$350,000,000 |
N/A |
1 |
$84,032,000 |
$1,020.00 |
$30 |
$1,050.00 |
7.50% Senior Notes due 2018 |
845467AE9 |
$600,000,000 |
N/A |
2 |
$173,433,000 |
$1,057.50 |
$30 |
$1,087.50 |
4.05% Senior Notes due 2020 |
845467AK5 |
$850,000,000 |
$50,000,000 |
3 |
$9,298,000 |
$970.00 |
$30 |
$1,000.00 |
(1) |
Does not include accrued interest, which will also be payable to but not including the applicable settlement date. |
(2) |
Includes the Early Tender Premium. |
The Company reserves the right, but is under no obligation, at any point following the Early Tender Time and before the Expiration Date, to accept for purchase any Notes validly tendered and not validly withdrawn prior to the Early Tender Time. The early settlement date will be determined at the Company's option and is currently expected to occur on July 20, 2016, subject to all conditions to the Amended Tender Offers having been either satisfied or waived by the Company as of the early settlement date.
Credit Suisse Securities (USA) LLC ("Credit Suisse") and Mitsubishi UFJ Securities (USA), Inc. ("MUFG") are the Lead Dealer Managers in the Amended Tender Offers. D.F. King & Co., Inc. ("D.F. King") has been retained to serve as both the Tender Agent and Information Agent for the Amended Tender Offers. Persons with questions regarding the Amended Tender Offers should contact Credit Suisse at (toll free) (800) 820-1653 or (collect) (212) 538-2147 or MUFG at (toll free) (877) 744-4532 or (collect) (212) 405-7481. Requests for the Offer to Purchase and the amendments thereto should be directed to D.F. King at (toll free) (866) 406-2283 or (collect) (212) 269-5550 or SWN@dfking.com.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Amended Tender Offers are being made only pursuant to the Offer to Purchase, as amended, and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Amended Tender Offers are required to be made by a licensed broker or dealer, the Amended Tender Offers will be deemed to be made on behalf of the Company by the Dealer Managers, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, July 14, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced an amendment with respect to its previously announced cash tender offers to purchase (as amended, the "Amended Tender Offers") its outstanding 3.30% Senior Notes due 2018, 7.50% Senior Notes due 2018 and 4.05% Senior Notes due 2020 (collectively, the "Notes") for a maximum aggregate purchase price (excluding accrued interest) of up to $750.0 million (the "Aggregate Maximum Purchase Price").
The amendment provides for an extension of the period during which validly tendered (and not validly withdrawn) Notes are eligible to receive the Early Tender Premium as (as defined in the Offer to Purchase (as defined below)) from 5:00 p.m., New York City time, on July 13, 2016 to 5:00 p.m., New York City time, on July 15, 2016 (such date and time, as it may be further extended, the "Early Tender Time").
Additionally, the Company announced that the financing condition to which the tender offers were subject has been satisfied and that the Amended Tender Offers will not include any amendments to the financing condition.
This announcement amends the Company's Offer to Purchase, dated June 29, 2016 (as amended, the "Offer to Purchase"). Other than the amendment described above, all terms and conditions in the Offer to Purchase remain unchanged.
The withdrawal deadline for tendered Notes was 5:00 p.m., New York City time, on July 13, 2016 (the "Withdrawal Deadline"). As a result, tendered Notes may not be withdrawn, except as required by applicable law.
The Company reserves the right, but is under no obligation, at any point following the Early Tender Time and before July 28, 2016, to accept for purchase any Notes validly tendered prior to the Early Tender Time. The early settlement date will be determined at the Company's option and is currently expected to occur on July 18, 2016, subject to all conditions to the Amended Tender Offers having been either satisfied or waived by the Company as of the early settlement date.
Credit Suisse Securities (USA) LLC ("Credit Suisse") and Mitsubishi UFJ Securities (USA), Inc. ("MUFG") are the Lead Dealer Managers in the Amended Tender Offers. D.F. King & Co., Inc. ("D.F. King") has been retained to serve as both the Tender Agent and Information Agent for the Amended Tender Offers. Persons with questions regarding the Amended Tender Offers should contact Credit Suisse at (toll free) (800) 820-1653 or (collect) (212) 538-2147 or MUFG at (toll free) (877) 744-4532 or (collect) (212) 405-7481. Requests for the Offer to Purchase should be directed to D.F. King at (toll free) (866) 406-2283 or (collect) (212) 269-5550 or SWN@dfking.com.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Amended Tender Offers are being made only pursuant to the Offer to Purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Amended Tender Offers are required to be made by a licensed broker or dealer, the Amended Tender Offers will be deemed to be made on behalf of the Company by the Dealer Managers, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, July 11, 2016 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2016 Second Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, July 22, 2016, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Second Quarter 2016 Earnings |
When: |
July 22, 2016 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
SPRING, Texas, July 5, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced the completion of its previously announced underwritten public offering of 98,900,000 shares of its common stock, with net proceeds from the offering to the company totaling approximately $1,247 million after underwriting discounts and offering expenses.
The net proceeds from the offering will be used to repay $375.0 million of the $750.0 million term loan Southwestern Energy entered into in November 2015 under the Amended and Restated Term Loan Credit Agreement with various lenders and Bank of America, N.A., as administrative agent and lender (the "2015 Term Loan"), and the remaining net proceeds of the offering will be used to fund Southwestern Energy's tender offers (the "Tender Offers") to purchase for cash, subject to certain conditions, up to $750.0 million aggregate purchase price, excluding accrued interest, of its 3.30% senior notes due 2018, 7.50% senior notes due 2018 and 4.05% senior notes due 2020, and for general corporate purposes, including the repayment of additional indebtedness outstanding under the 2015 Term Loan, the completion of wells already drilled or the funding of other capital projects. If the Tender Offers are not consummated, or the aggregate amount of securities tendered in the Tender Offers and accepted for payment is less than the net proceeds of the common stock offering dedicated for that purpose, Southwestern Energy may use the remainder of those proceeds for general corporate purposes, including the repayment of additional indebtedness outstanding under the 2015 Term Loan, the completion of wells already drilled or the funding of other capital projects. Payment of the $375.0 million of the 2015 Term Loan has the effect of extending its maturity to December 14, 2020.
Credit Suisse, BofA Merrill Lynch, J.P. Morgan, Citigroup, and Mizuho Securities acted as joint book-running managers for the offering. The offering was made under an effective automatic shelf registration statement on Form S-3 (Registration No. 333-208074) filed by Southwestern Energy with the Securities and Exchange Commission ("SEC") and only by means of a prospectus supplement and accompanying base prospectus. Prospective investors should read the prospectus supplement and the accompanying base prospectus included in the registration statement and other documents Southwestern Energy has filed with the SEC for more complete information about Southwestern Energy and the offering. These documents are available at no charge by visiting EDGAR on the SEC website at http://www.sec.gov.
Alternatively, a copy of the prospectus supplement and accompanying base prospectus relating to these securities may be obtained, when available, from:
Credit Suisse Securities (USA), LLC
Attn: Prospectus Department
One Madison Avenue
New York, NY 10010
Phone: (800) 221-1037
Email: newyork.prospectus@credit-suisse.com
BofA Merrill Lynch
200 North College Street, 3rd Floor
Charlotte, NC 28255-0001
Attn: Prospectus Department
Email: dg.prospectus_requests@baml.com
Citigroup Global Markets Inc.
c/o Broadridge Financial Solutions
1155 Long Island Avenue
Edgewood, NY 11717
Toll-Free: (800) 831-9146
J.P. Morgan Securities LLC
c/o Broadridge Financial Solutions
1155 Long Island Avenue
Edgewood, NY 11717
Toll-free 866-803-9204
Email: prospectus-eg_fi@jpmchase.com
Mizuho Securities USA Inc.
320 Park Avenue, 12th Floor
New York, NY 10022-6815
Attn: Equity Capital Markets
(212) 205-7600
This news release shall not constitute an offer to sell or the solicitation of an offer to buy nor shall there be any sale of, or any solicitation of an offer to buy, these securities in any state or jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing.
This news release contains forward-looking statements. Forward-looking statements relate to future events, including, but not limited to, anticipated results of operations, business strategies, other aspects of Southwestern Energy's operations or operating results and the use of proceeds of the offering. 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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws applicable to the company's 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 the company's business generally as set forth in the company's filings with the SEC. 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.
SOURCE Southwestern Energy Company
HOUSTON, June 29, 2016 /PRNewswire/ -- Southwestern Energy Company ("Southwestern Energy") (NYSE: SWN) priced its previously announced underwritten public offering of 86,000,000 shares of its common stock on June 29, 2016 (the "offering"). The offering was upsized from the previously announced offering of 75,000,000 shares of Southwestern Energy's common stock. Total gross proceeds of the offering (before underwriter's discounts and commissions and estimated offering expenses) will be approximately $1.1 billion. The underwriter intends to offer the shares from time to time for sale in one or more transactions on the New York Stock Exchange, in the over-the-counter market, through negotiated transactions or otherwise at market prices prevailing at the time of sale, at prices related to prevailing market prices or at negotiated prices. In addition, Southwestern Energy granted the respective underwriters a 30-day option to purchase up to 12,900,000 additional shares of its common stock. The net proceeds from the offering will be used to repay $375.0 million of the $750.0 million term loan Southwestern Energy entered into in November 2015 under the Amended and Restated Term Loan Credit Agreement with various lenders and Bank of America, N.A., as administrative agent and lender (the "2015 Term Loan"), and the remaining net proceeds of the offering, together with cash on hand, to fund Southwestern Energy's tender offers (the "Tender Offers") to purchase for cash, subject to certain conditions, up to $750.0 million aggregate purchase price, excluding accrued interest, of its 3.30% senior notes due 2018, 7.50% senior notes due 2018 and 4.05% senior notes due 2020. If the Tender Offers are not consummated, or the aggregate amount of securities tendered in the Tender Offers and accepted for payment is less than the net proceeds of the common stock offering dedicated for that purpose, Southwestern Energy may use the remainder of those proceeds for general corporate purposes, including the repayment of additional indebtedness outstanding under the 2015 Term Loan, the completion of wells already drilled or the funding of other capital projects. The net proceeds from any exercise by the underwriters of their option to purchase additional shares of common stock will be used to fund a portion of the Tender Offers or for general corporate purposes as described above. The closing of the offering, which is expected to occur on July 5, 2016, is subject to customary closing conditions.
Credit Suisse Securities (USA) LLC, Citigroup Global Markets Inc., J.P. Morgan Securities LLC, Merrill Lynch, Pierce, Fenner & Smith Incorporated, and Mizuho Securities USA Inc. are acting as joint book-running managers for the offering.
The offering is being made under an effective automatic shelf registration statement on Form S-3 (Registration No. 333-208074) filed by Southwestern Energy with the Securities and Exchange Commission ("SEC") and only by means of a prospectus supplement and accompanying base prospectus. A preliminary prospectus supplement has been filed with the SEC to which this communication relates. Prospective investors should read the preliminary prospectus supplement and the accompanying base prospectus included in the registration statement and other documents Southwestern Energy has filed with the SEC for more complete information about Southwestern Energy and the offering. These documents are available at no charge by visiting EDGAR on the SEC website at http://www.sec.gov.
Alternatively, a copy of the prospectus supplement and accompanying base prospectus relating to these securities may be obtained, when available, from:
Credit Suisse Securities (USA), LLC
Attn: Prospectus Department
One Madison Avenue
New York, NY 10010
Phone: (800) 221-1037
Email: newyork.prospectus@credit-suisse.com
BofA Merrill Lynch
Attention: Prospectus Department
222 Broadway, 7th Floor
New York, NY 10038
Email: dg.prospectus_requests@baml.com
Citigroup Global Markets Inc.
c/o Broadridge Financial Solutions
1155 Long Island Avenue
Edgewood, NY 11717
prospectus@citi.com
Toll-Free: (800) 831-9146
J.P. Morgan Securities LLC
c/o Broadridge Financial Solutions
1155 Long Island Avenue
Edgewood, NY 11717
Telephone number 866-803-9204
Mizuho Securities USA Inc.
320 Park Avenue, 12th Floor
New York, NY 10022-6815
Attn: Equity Capital Markets
(212) 205-7600
This press release shall not constitute an offer to sell or the solicitation of an offer to buy these securities, nor shall there be any sale of these securities, in any state or jurisdiction in which such offer, solicitation or sale of these securities would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction. This press release is not an offer to purchase or the solicitation of an offer to sell any notes. The Tender Offers will be made subject to the terms of an offer to purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers will be deemed to be made on behalf of Southwestern Energy by the dealer managers or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing.
This news release contains forward-looking statements. Forward-looking statements relate to future events, including, but not limited to, anticipated results of operations, business strategies, other aspects of Southwestern Energy's operations or operating results, the proposed offering and the use of proceeds of the offering. 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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws applicable to the company's 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 the company's business generally as set forth in the company's filings with the SEC. 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.
SOURCE Southwestern Energy Company
HOUSTON, June 29, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) (the "Company") today announced that it has launched offers to purchase for cash (collectively, the "Tender Offers" and each a "Tender Offer") its outstanding senior notes listed in the table below (collectively, the "Notes"), upon the terms and conditions described in the Company's Offer to Purchase dated June 29, 2016 (the "Offer to Purchase").
Aggregate |
Dollars per U.S. $1,000 Principal | ||||||
Title of Notes |
CUSIP Number |
Sub-Cap |
Acceptance Priority Level |
Tender Offer Consideration(1) (U.S. $) |
Early Tender Premium (U.S. $) |
Total | |
3.30% Senior Notes due 2018 |
845467AJ8 |
$350,000,000 |
N/A |
1 |
996.25 |
$30 |
$1,026.25 |
7.50% Senior Notes due 2018 |
845467AE9 |
$600,000,000 |
N/A |
2 |
1033.75 |
$30 |
$1,063.75 |
4.05% Senior Notes due 2020 |
845467AK5 |
$850,000,000 |
$50,000,000 |
3 |
945.00 |
$30 |
$975.00 |
(1) Does not include accrued interest, which will also be payable to but not including the applicable settlement date. | |||||||
(2) Includes the Early Tender Premium. |
Specifically, the Company is offering to purchase an aggregate principal amount of Notes that will not result in an aggregate amount that all holders of the Notes are entitled to receive in the Tender Offers, excluding accrued and unpaid interest, that exceeds $750,000,000 (such purchase price, the "Aggregate Maximum Purchase Price").
Subject to the Aggregate Maximum Purchase Price, the amount of a series of Notes that is purchased in the Tender Offers on any settlement date will be based on the order of priority set forth in the above table (with 1 being the highest Acceptance Priority Level and 3 being the lowest Acceptance Priority Level), subject to the proration arrangements applicable to the Tender Offers. In addition, no more than $50.0 million of the Company's 4.05% senior notes due 2020 (the "4.05% 2020 Notes") will be purchased in the Tender Offers (subject to increase by the Company, the "Sub-Cap").
The Tender Offers will expire at 12:00 midnight, New York City time, at the end of the day on July 27, 2016, unless extended or earlier terminated by the Company (the "expiration date"). No tenders submitted after the expiration date will be valid. Subject to the terms and conditions of the Tender Offers, the consideration for each $1,000 principal amount of the Notes validly tendered and accepted for purchase pursuant to the Tender Offers will be the applicable Tender Offer Consideration set forth in the above table. Holders of Notes that are validly tendered prior to 5:00 p.m., New York City time, on July 13, 2016 (subject to extension, the "early tender date") and accepted for purchase pursuant to the applicable Tender Offer will receive the applicable Total Consideration set forth in the above table, which includes the applicable Tender Offer Consideration plus the applicable Early Tender Premium. Holders of Notes tendering their Notes after the early tender date will not be eligible to receive the Early Tender Premium. All Notes validly tendered and accepted for purchase pursuant to the Tender Offers will also receive accrued and unpaid interest on such Notes from the last interest payment date with respect to those Notes to, but not including, the applicable settlement date.
Tendered Notes may be withdrawn from the Tender Offers prior to 5:00 p.m., New York City time, on July 13, 2016, unless extended by the Company (the "withdrawal deadline"). Holders of Notes who tender their Notes after the withdrawal deadline, but prior to the expiration date, may not withdraw their tendered Notes. The Company reserves the right, but is under no obligation, to increase the Aggregate Maximum Purchase Price or the Sub-Cap at any time, subject to applicable law. If the Company increases the Aggregate Maximum Purchase Price or the Sub-Cap, it does not expect to extend the withdrawal deadline, subject to applicable law.
The Company reserves the right, but is under no obligation, at any point following the early tender date and before the expiration date, to accept for purchase any Notes validly tendered prior to the early tender date. The early settlement date will be determined at the Company's option and is currently expected to occur on July 14, 2016, subject to all conditions to the Tender Offers having been either satisfied or waived by the Company as of the early settlement date. The Company will purchase any remaining Notes that have been validly tendered and accepted in the Tender Offers prior to the expiration date promptly following the expiration date. The final settlement date is expected to occur on July 28, 2016, the first business day following the expiration date.
Subject to the Aggregate Maximum Purchase Price, the Sub-Cap and proration, the Company will accept Notes for purchase in the Tender Offers in the following order:
(i) with respect to Notes validly tendered prior to the early tender date, all Notes having a higher Acceptance Priority Level will be accepted before any Notes validly tendered prior to the early tender date having a lower Acceptance Priority Level are accepted in the Tender Offers; and
(ii) with respect to Notes validly tendered after the early tender date, all Notes having a higher Acceptance Priority Level will be accepted before any Notes validly tendered after the early tender date having a lower Acceptance Priority Level are accepted in the Tender Offers.
If an aggregate principal amount of Notes is validly tendered by the early tender date such that the aggregate purchase price for such Notes equals or exceeds the Aggregate Maximum Purchase Price, holders who validly tender Notes after the early tender date will not have any of their Notes accepted for purchase. Notes validly tendered prior to the early tender date will be accepted for purchase in priority to Notes validly tendered after the early tender date, even if Notes validly tendered after the early tender date have a higher Acceptance Priority Level than Notes validly tendered prior to the early tender date. Acceptance for tenders of Notes of a series may be subject to proration if the aggregate principal amount of such series of Notes validly tendered would result in an aggregate purchase price that exceeds the Aggregate Maximum Purchase Price. Acceptance for tenders of the 4.05% 2020 Notes may be subject to proration if the aggregate principal amount of the 4.05% 2020 Notes validly tendered and not validly withdrawn is greater than the Sub-Cap.
The Tender Offers are not conditioned upon the tender of any minimum principal amount of Notes of any series. However, the Tender Offers are subject to, and conditioned upon, the satisfaction or waiver of certain conditions described in the Offer to Purchase, including the Company's concurrently announced offering of shares of its common stock (the "equity offering") resulting in net proceeds of at least $900,000,000 to the Company.
The Company intends to fund the Tender Offers, including accrued and unpaid interest and fees and expenses payable in connection with the Tender Offers, with proceeds from the equity offering and cash on hand.
The purpose of the Tender Offers is to retire debt. If the Tender Offers are not consummated, or if the amount of Notes accepted for purchase in the Tender Offers results in the payment of less than the Aggregate Maximum Purchase Price, the Company may use the remaining amount of proceeds from the equity offering originally dedicated to the Tender Offers to repay or retire other outstanding indebtedness.
Credit Suisse Securities (USA) LLC ("Credit Suisse") and Mitsubishi UFJ Securities (USA), Inc. ("MUFG") are the Lead Dealer Managers in the Tender Offers. D.F. King & Co., Inc. ("D.F. King") has been retained to serve as both the Tender Agent and Information Agent for the Tender Offers. Persons with questions regarding the Tender Offers should contact Credit Suisse at (toll free) (800) 820-1653 or (collect) (212) 538-2147 or MUFG at (toll free) (877) 744-4532 or (collect) (212) 405-7481. Requests for the Offer to Purchase should be directed to D.F. King at (toll free) (866) 406-2283 or (collect) (212) 269-5550 or SWN@dfking.com.
This news release shall not constitute an offer to sell, a solicitation to buy or an offer to purchase or sell any securities. The Tender Offers are being made only pursuant to the Offer to Purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers will be deemed to be made on behalf of the Company by the Dealer Managers, or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, June 29, 2016 /PRNewswire/ -- Southwestern Energy Company ("Southwestern Energy") (NYSE: SWN) today announced the commencement of an underwritten public offering of 75,000,000 shares of its common stock (the "offering"), subject to market and other conditions. Southwestern Energy intends to grant the respective underwriters a 30-day option to purchase up to 11,250,000 additional shares of its common stock. The underwriters intend to offer the shares from time to time for sale in one or more transactions on the New York Stock Exchange, in the over-the-counter market, through negotiated transactions or otherwise at market prices prevailing at the time of sale, at prices related to prevailing market prices or at negotiated prices. The net proceeds from the offering will be used to repay $375.0 million of the $750.0 million term loan Southwestern Energy entered into in November 2015 under the Amended and Restated Term Loan Credit Agreement with various lenders and Bank of America, N.A., as administrative agent and lender (the "2015 Term Loan"), and the remaining net proceeds of the offering, together with cash on hand, to fund Southwestern Energy's tender offers (the "Tender Offers") to purchase for cash, subject to certain conditions, up to $750.0 million aggregate purchase price, excluding accrued interest, of its 3.30% senior notes due 2018, 7.50% senior notes due 2018 and 4.05% senior notes due 2020. If the Tender Offers are not consummated, or the aggregate amount of securities tendered in the Tender Offers and accepted for payment is less than the net proceeds of the common stock offering dedicated for that purpose, Southwestern Energy may use the remainder of those proceeds for general corporate purposes, including the repayment of additional indebtedness outstanding under the 2015 Term Loan, the completion of wells already drilled or the funding of other capital projects. The net proceeds from any exercise by the underwriters of their option to purchase additional shares of common stock will be used to fund a portion of the Tender Offers or for general corporate purposes as described above.
Credit Suisse Securities (USA) LLC is acting as lead book-running manager for the offering.
The offering is being made under an effective automatic shelf registration statement on Form S-3 (Registration No. 333-208074) filed by Southwestern Energy with the Securities and Exchange Commission ("SEC") and only by means of a prospectus supplement and accompanying prospectus. A preliminary prospectus supplement has been filed with the SEC to which this communication relates. Prospective investors should read the preliminary prospectus supplement and the accompanying prospectus included in the registration statement and other documents Southwestern Energy has filed with the SEC for more complete information about Southwestern Energy and the offering. These documents are available at no charge by visiting EDGAR on the SEC website at http://www.sec.gov. Alternatively, copies of the base prospectus and the preliminary prospectus supplement may be obtained from Credit Suisse at: Credit Suisse Securities (USA) LLC, Prospectus Department, at One Madison Avenue, New York, New York 10010, by telephone at 1 (800) 221-1037 or e-mail: newyork.prospectus@credit-suisse.com.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy these securities, nor shall there be any sale of these securities, in any state or jurisdiction in which such offer, solicitation or sale of these securities would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction. This press release is not an offer to purchase or the solicitation of an offer to sell any notes. The Tender Offers will be made subject to the terms of an offer to purchase and only in such jurisdictions as is permitted under applicable law. In any jurisdiction in which the Tender Offers are required to be made by a licensed broker or dealer, the Tender Offers will be deemed to be made on behalf of Southwestern Energy by the dealer managers or one or more registered brokers or dealers that are licensed under the laws of such jurisdiction.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing.
This news release contains forward-looking statements. Forward-looking statements relate to future events, including, but not limited to, anticipated results of operations, business strategies, other aspects of Southwestern Energy's operations or operating results, the proposed offering and the use of proceeds of the offering. 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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws applicable to the company's 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 the company's business generally as set forth in the company's filings with the SEC. 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.
SOURCE Southwestern Energy Company
HOUSTON, June 27, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that it has entered into agreements with substantially all of its bank group for its $2.0 billion revolving line of credit and its $750 million term loan to extend maturities and modify certain other terms and conditions of the credit facilities.
"We have taken a significant step in managing our debt maturities and liquidity," said Bill Way, President and Chief Executive Officer. "We have extended liquidity availability and a major portion of our debt by two years with only modest additional cost and covenants. These actions deliver on the plan we discussed previously to strengthen the balance sheet, which is a key component of setting the Company up for value adding growth. We truly value the strong relationships we have with our bank group and appreciate the hard work and trust that the participating banks demonstrated in us throughout this amendment and extension process."
The principal terms include the following:
A more detailed description of the new and the amended credit agreements, along with copies of the agreements, appears in a Current Report on Form 8-K that the company contemporaneously is filing with the Securities and Exchange Commission.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, June 14, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that an authorized committee of its Board of Directors declared a quarterly dividend of $15.625 per share on its 6.25% Series B Mandatory Convertible Preferred Stock, payable on July 15, 2016, to holders of record on July 1, 2016. This equates to $0.78125 for each depositary share, which represents a 1/20th interest in a share of the Series B preferred stock. The dividend is for the period beginning on April 15, 2016 and ending on July 14, 2016.
The company has elected to pay this dividend in shares of common stock of the company to the extent permitted by the certificate of designations for the Series B preferred stock. Common shares issued will be listed and tradable on the New York Stock Exchange.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, June 9, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) announced today that it has entered into a definitive agreement with Antero Resources Corporation to sell approximately 55,000 net acres in West Virginia for $450 million. The cash proceeds from the transaction are expected to be used to reduce the principal balance of the company's $750 million term loan due in November 2018.
The properties are located in Doddridge, Harrison, Marion, Monongalia, Pleasants, Ritchie, Tyler and Wetzel Counties and are currently producing from the Marcellus Shale. Net production from this acreage is approximately 14 MMcfe per day, primarily from non-operated wells, and proved reserves on this acreage were 11 Bcfe as of December 31, 2015. The Company has no current plans to drill on these properties before 2023.
"This transaction is one step on delivering on the commitment we made to strengthen our balance sheet in 2016," remarked Bill Way, President and Chief Executive Officer of Southwestern Energy. "We are bringing forward the value of acreage that is much longer dated in our development plans, enabling us to take action and proactively reduce outstanding debt. Together with the progress we are making on margin enhancement, this sale further strengthens both the Company's financial flexibility and our bridge to value-added growth for shareholders."
The transaction is expected to close in the third quarter of 2016, subject to customary closing conditions and purchase price adjustments.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, April 25, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that its Board of Directors intends to elect independent director Catherine A. Kehr as Chairman of the Board following the annual meeting of shareholders on May 17, 2016. Ms. Kehr has served as a director since 2011 and as Presiding Director since 2014, as chairman of the Board's Nominating and Governance Committee and on its Audit Committee. She will succeed Steve Mueller, who as previously announced is retiring as a director at the May annual meeting.
"Cathy's insights as a former portfolio manager for a major investment firm, her broad experience in energy and financial markets, and her leadership and dedication to Southwestern Energy demonstrated in her years on our Board position her well to lead our Board," said Bill Way, President and Chief Executive Officer. "I look forward to working closely with Cathy to enhance value for our shareholders."
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, April 21, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the quarter ended March 31, 2016 as well as an update to the progress made on the strategic initiatives disclosed in February 2016. First quarter highlights include:
"We began the year by leveraging the momentum built by our operational teams in 2015 and are making good progress executing on our strategic initiatives to position the Company for long-term value creation," remarked Bill Way, President and Chief Executive Officer of Southwestern Energy. "While adjusting activity levels to align with the commodity prices, we exceeded guidance on production volumes and associated costs by continuing our laser focus on efficiency improvements. The actions we are taking to further strengthen our balance sheet, enhance operating margins and optimize cash flow will continue to provide benefits in the current environment, and will enable us to enhance shareholder value as commodity prices improve."
First Quarter of 2016 Financial Results
For the first quarter of 2016, Southwestern reported an adjusted net loss attributable to common stock (reconciled below) of $32 million, or $0.08 per diluted share and a net loss attributable to common stock of $1.2 billion, or $3.03 per diluted share. This compares to adjusted net income attributable to common stock of $84 million, or $0.22 per diluted share, and net income attributable to common stock of $46 million, or $0.12 per diluted share, in the first quarter of 2015.
Net cash (reconciled below) was $147 million for the first quarter of 2016, compared to $493 million for the same period in 2015. On a GAAP basis, net cash provided by operating activities was $92 million for the first quarter of 2016, compared to $541 million in the first quarter of 2015.
The first quarter of 2015 included the operating results from our gathering system in northeast Pennsylvania and our conventional E&P assets in East Texas and the Arkoma basin which were divested during the second quarter of 2015.
E&P Segment – The operating loss from the Company's E&P segment was $65 million for the first quarter of 2016 (reconciled below), when excluding the non-cash impairment and restructuring charges, compared to operating income of $78 million for the same period in 2015. The decrease was primarily due to lower realized natural gas prices along with decreases in our realized oil and NGL prices. On a GAAP basis, the operating loss from the Company's E&P segment was $1.2 billion for the first quarter of 2016, down from operating income of $78 million during the first quarter of 2015 primarily driven by the $1.0 billion non-cash impairment charge.
Net production totaled 237 Bcfe in the first quarter of 2016, up from 233 Bcfe in the first quarter of 2015. The quarter included 103 Bcf from the Fayetteville Shale, 94 Bcf from Northeast Appalachia and 40 Bcfe from Southwest Appalachia. This compares to 115 Bcf from the Fayetteville Shale, 83 Bcf from Northeast Appalachia and 30 Bcfe from Southwest Appalachia in the first quarter of 2015.
Including the effect of hedges, Southwestern's average realized gas price in the first quarter of 2016 was $1.48 per Mcf, down from $2.99 per Mcf in the first quarter of 2015. The Company's commodity hedging activities increased its average realized gas price by $0.04 per Mcf during the first quarter of 2016, compared to an increase of $0.36 per Mcf during the same period in 2015. As of April 19, 2016, the Company had approximately 107 Bcf of its remaining 2016 forecasted gas production protected at an average price of $2.43 per Mcf. A detailed breakdown of the Company's 2016 hedges is shown below:
2016 Gas Hedges | ||||||||||||||
Q1 |
Q2 |
Q3 |
Q4 |
Total | ||||||||||
Fixed Price Swaps (Bcf) |
5 |
24 |
25 |
15 |
69 | |||||||||
Fixed Price Swaps ($/Mcf) |
$ |
2.60 |
$ |
2.47 |
$ |
2.47 |
$ |
2.53 |
$ |
2.49 | ||||
Put Options (Bcf) |
- |
26 |
13 |
4 |
43 | |||||||||
Put Options ($/Mcf) |
$ |
- |
$ |
2.35 |
$ |
2.34 |
$ |
2.34 |
$ |
2.35 | ||||
Total (Bcf) |
5 |
50 |
38 |
19 |
112 | |||||||||
Total ($/Mcf) |
$ |
2.60 |
$ |
2.41 |
$ |
2.42 |
$ |
2.49 |
$ |
2.44 |
Like most producers, the Company typically sells its natural gas at a discount to NYMEX settlement prices. This discount includes a basis differential, third-party transportation charges and fuel charges. Disregarding the impact of hedges, the Company's average price received for its gas production during the first quarter of 2016 was approximately $0.65 per Mcf lower than average NYMEX settlement prices, compared to approximately $0.35 per Mcf lower than average NYMEX settlement prices during the first quarter of 2015. As of March 31, 2016, we have attempted to mitigate the volatility of basis differentials by protecting basis on approximately 160 Bcf our remaining 2016 expected natural gas production through physical sales arrangements at a basis differential to NYMEX natural gas prices of approximately ($0.19) per Mcf.
Lease operating expenses per unit of production for the Company's E&P segment were $0.88 per Mcfe in the first quarter of 2016, compared to $0.92 per Mcfe in the first quarter of 2015. The decrease was primarily due to the successful renegotiation of our existing gathering and processing rates for our Southwest Appalachia production.
General and administrative expenses per unit of production were $0.19 per Mcfe in the first quarter of 2016, compared to $0.24 per Mcfe in the first quarter of 2015, down primarily due to a decrease in employee costs. This excludes the restructuring charges associated with the workforce reduction, which were $58 million for the E&P segment in the first quarter of 2016.
Taxes other than income taxes were $0.08 per Mcfe in the first quarter of 2016, compared to $0.12 per Mcfe in the first quarter of 2015. Taxes other than income taxes per Mcfe vary from period to period due to changes in severance and ad valorem taxes that result from the mix of the Company's production volumes and fluctuations in commodity prices.
The Company's full cost pool amortization rate decreased to $0.49 per Mcfe in the first quarter of 2016, compared to $1.15 per Mcfe in the first quarter of 2015. The amortization rate is impacted by the timing and amount of reserve additions, the costs associated with those additions, revisions of previous reserve estimates due to both price and well performance, write-downs that result from full cost ceiling tests, proceeds from the sale of properties that reduce the full cost pool and the levels of costs subject to amortization. The Company cannot predict its future full cost pool amortization rate with accuracy due to the variability of each of the factors discussed above, as well as other factors.
Midstream – Adjusted operating income (reconciled below) for the Company's Midstream segment, comprised of gathering and marketing activities, was $63 million for the first quarter of 2016, excluding the impacts from restructuring charges. This is down from $88 million for the same period in 2015. The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale and the sale of the Company's northeast Pennsylvania gathering assets. On a GAAP basis, operating income for its Midstream segment was $60 million for the first quarter of 2016, compared to $88 million for the same period in 2015.
Capital Structure and Investments – At March 31, 2016, the Company had approximately $4.8 billion in net long-term debt, including $1.55 billion of cash temporarily borrowed on its revolving credit facility for the final two days of the quarter. The $1.55 billion was repaid on April 1, 2016. The revolving credit facility remains unsecured with a maturity date of December 2018. The only financial covenant included in the Company's revolving credit facility, debt to book capitalization adjusted for ceiling test impairments, was 45% at March 31, 2016. This is well below the covenant limit of 60% despite the $1.55 billion temporary draw on the revolver at quarter-end to maximize secured debt capacity.
During the first quarter of 2016, Southwestern invested a total of $122 million. This is down from $518 million in the first quarter of 2015, excluding $653 million associated with the closing the Appalachia transactions that closed in December 2014 and January 2015. The $122 million includes approximately $120 million invested in its E&P business and $2 million invested in its Midstream segment.
E&P Operations Review
During the first quarter of 2016, Southwestern invested approximately $120 million in its E&P business, including $58 million in investment capital and $62 in capitalized interest and expenses. Consistent with guidance, the Company placed 12 wells to sales in the first quarter and expects to put 20 to 30 wells to sales during 2016.
In Northeast Appalachia, the Company completed 6 wells and placed 3 wells on production in the first quarter of 2016. This activity resulted in net gas production of 94 Bcf, up 13% from 83 Bcf in the first quarter of 2015. Gross operated production in Northeast Appalachia was approximately 1.2 Bcf per day at March 31, 2016. The Company expects to place an additional 5 wells on production in the second quarter of 2016 in this operating area.
In Southwest Appalachia, net production of 40 Bcfe in the first quarter of 2016 was 33% higher than the 30 Bcfe of net production in the same period of 2015. The gross exit production rate in Southwest Appalachia was approximately 670 MMcfe per day at March 31, 2016. The wells drilled and completed by Southwestern to date continue to deliver impressive well results from this acreage. One example of this is the Alice Edge pad, which includes 9 producing wells. This pad is currently producing 85 MMcfe per day after almost 5 months of production.
In the first quarter of 2016, Southwestern's net gas production from the Fayetteville Shale was 103 Bcf, compared to 115 Bcf in the first quarter of 2015. Gross operated gas production in the Fayetteville Shale was approximately 1.6 Bcf per day at March 31, 2016. The Company completed 3 wells and placed 9 wells on production in the first quarter of 2016 and expects to place an additional 6 wells on production in the second quarter in this operating area.
Update on 2016 Strategic Initiatives
The Company made progress on each of the strategic initiatives discussed in February 2016. These initiatives included strengthening the balance sheet, enhancing margins and optimizing its portfolio of premier quality assets.
The Company also continued its proactive plan to strengthen the balance sheet and address its 2018 debt maturities. In addition to the steps discussed above to maximize secured and subsidiary debt capacity, progress was also made on potential asset sales as data rooms were opened and remain in process currently.
While cost savings played a significant role to the margin enhancement effort, improvements were realized on revenues as well. The Company's firm transportation and sales portfolio once again provided significant benefits. For the first quarter of 2016, the firm transportation and sales portfolio added over $30 million in value compared to selling produced volumes into local production area indices. Despite incurring one of the warmest winters on record, the Company's full year discount to NYMEX is still expected to be within the guidance range provided. The flexible portfolio of capacity to sell volumes at various hubs has provided significant benefits to mitigate the impacts of this warmer start to the year.
The Company is also working to improve learnings from historical drilling and completion techniques to better understand the optimal methods to use when activity is increased. These learnings will improve our already advantaged ability to restart our development activities once commodity prices improve. With this additional knowledge, the Company expects to generate even better long-term value for shareholders as well economics are continuously optimized.
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. 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 adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's performance is measured relative to the performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the three months ended March 31, 2016 and March 31, 2015. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended March 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Net income (loss) attributable to common stock: |
|||||
Net income (loss) attributable to common stock |
$ |
(1,159) |
$ |
46 | |
Add back: |
|||||
Impairment of natural gas and oil properties (net of taxes) |
641 |
- | |||
Restructuring costs (net of taxes) |
40 |
- | |||
Transaction costs (net of taxes) |
- |
27 | |||
Loss on certain derivatives (net of taxes) |
13 |
11 | |||
Adjustments due to inventory valuation (net of taxes) |
2 |
- | |||
Adjustments due to discrete tax items(1) |
431 |
- | |||
Adjusted net income (loss) attributable to common stock |
$ |
(32) |
$ |
84 |
3 Months Ended March 31, | |||||
2016 |
2015 | ||||
Diluted earnings per share: |
|||||
Diluted earnings per share |
$ |
(3.03) |
$ |
0.12 | |
Add back: |
|||||
Impairment of natural gas and oil properties (net of taxes) |
1.67 |
- | |||
Restructuring costs (net of taxes) |
0.11 |
- | |||
Transaction costs (net of taxes) |
- |
0.07 | |||
Loss on certain derivatives (net of taxes) |
0.03 |
0.03 | |||
Adjustments due to inventory valuation (net of taxes) |
0.01 |
- | |||
Adjustments due to discrete tax items(1) |
1.13 |
- | |||
Adjusted diluted earnings per share |
$ |
(0.08) |
$ |
0.22 |
(1) |
2016 primarily relates to the exclusion of certain discrete tax adjustments in the first quarter of 2016 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0%. |
3 Months Ended March 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Cash flow from operating activities: |
|||||
Net cash provided by operating activities |
$ |
92 |
$ |
541 | |
Add back: |
|||||
Changes in operating assets and liabilities |
33 |
(48) | |||
Restructuring charges |
22 |
- | |||
Net Cash |
$ |
147 |
$ |
493 |
3 Months Ended March 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
E&P segment operating income (loss): |
|||||
E&P segment operating income (loss) |
$ |
(1,160) |
$ |
78 | |
Add back: |
|||||
Impairment of natural gas and oil properties |
1,034 |
- | |||
Restructuring charges |
61 |
- | |||
Adjusted E&P segment operating income (loss) |
$ |
(65) |
$ |
78 |
3 Months Ended March 31, | |||||
2016 |
2015 | ||||
(in millions) | |||||
Midstream segment operating income: |
|||||
Midstream segment operating income |
$ |
60 |
$ |
88 | |
Add back: |
|||||
Restructuring charges |
3 |
- | |||
Adjusted Midstream segment operating income |
$ |
63 |
$ |
88 |
Southwestern management will host a teleconference call on Friday, April 22, 2016 at 10:00 a.m. Eastern to discuss its first quarter 2016 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
OPERATING STATISTICS (Unaudited) |
Page 1 of 5 | ||||
Southwestern Energy Company and Subsidiaries |
|||||
For the three months ended | |||||
March 31, | |||||
2016 |
2015 | ||||
Exploration & Production |
|||||
Production |
|||||
Gas production (Bcf) |
213 |
219 | |||
Oil production (MBbls) |
607 |
545 | |||
NGL production (MBbls) |
3,376 |
1,766 | |||
Total production (Bcfe) |
237 |
233 | |||
Commodity Prices |
|||||
Average realized gas price per Mcf, including hedges |
$ |
1.48 |
$ |
2.99 | |
Average realized gas price per Mcf, excluding hedges |
$ |
1.44 |
$ |
2.63 | |
Average oil price per Bbl |
$ |
18.65 |
$ |
30.90 | |
Average NGL price per Bbl |
$ |
4.98 |
$ |
10.35 | |
Summary of Derivative Activity in the Statement of Operations |
|||||
Settled commodity amounts included in "Operating Revenues" (in millions) |
$ |
– |
$ |
42 | |
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
8 |
$ |
36 | |
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(18) |
$ |
(18) | |
Average unit costs per Mcfe |
|||||
Lease operating expenses |
$ |
0.88 |
$ |
0.92 | |
General and administrative expenses (1) |
$ |
0.19 |
$ |
0.24 | |
Taxes, other than income taxes (2) |
$ |
0.08 |
$ |
0.12 | |
Full cost pool amortization |
$ |
0.49 |
$ |
1.15 | |
Midstream |
|||||
Volumes marketed (Bcfe) |
279 |
260 | |||
Volumes gathered (Bcf) |
165 |
233 |
(1) |
Excludes $58 million of restructuring charges in 2016. |
(2) |
Excludes $3 million of restructuring charges in 2016. |
STATEMENTS OF OPERATIONS (Unaudited) |
Page 2 of 5 | ||||
Southwestern Energy Company and Subsidiaries |
|||||
For the three months ended | |||||
March 31, | |||||
2016 |
2015 | ||||
(in millions, except share/per share amounts) | |||||
Operating Revenues |
|||||
Gas sales |
$ |
315 |
$ |
625 | |
Oil sales |
11 |
17 | |||
NGL sales |
17 |
18 | |||
Marketing |
198 |
225 | |||
Gas gathering |
38 |
48 | |||
579 |
933 | ||||
Operating Costs and Expenses |
|||||
Marketing purchases |
196 |
222 | |||
Operating expenses |
165 |
155 | |||
General and administrative expenses |
54 |
68 | |||
Restructuring charges |
64 |
– | |||
Depreciation, depletion and amortization |
143 |
293 | |||
Impairment of natural gas and oil properties |
1,034 |
– | |||
Taxes, other than income taxes |
23 |
30 | |||
1,679 |
768 | ||||
Operating Income (Loss) |
(1,100) |
165 | |||
Interest Expense |
|||||
Interest on debt |
53 |
50 | |||
Other interest charges |
2 |
49 | |||
Interest capitalized |
(41) |
(48) | |||
14 |
51 | ||||
Other Loss, Net |
(3) |
(1) | |||
Gain (Loss) on Derivatives |
(14) |
14 | |||
Income (Loss) Before Income Taxes |
(1,131) |
127 | |||
Provision for Income Taxes |
|||||
Deferred |
1 |
49 | |||
Net Income (Loss) |
(1,132) |
78 | |||
Mandatory convertible preferred stock dividend |
27 |
25 | |||
Participating securities - mandatory convertible preferred stock |
– |
7 | |||
Net Income (Loss) Attributable to Common Stock |
$ |
(1,159) |
$ |
46 | |
Earnings (Loss) Per Common Share |
|||||
Basic |
$ |
(3.03) |
$ |
0.12 | |
Diluted |
$ |
(3.03) |
$ |
0.12 | |
Weighted Average Common Shares Outstanding | |||||
Basic |
382,870,847 |
375,444,030 | |||
Diluted |
382,870,847 |
375,578,054 |
BALANCE SHEETS (Unaudited) |
Page 3 of 5 | |||||
Southwestern Energy Company and Subsidiaries |
||||||
March 31, |
December 31, | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
1,884 |
$ |
393 | ||
Property and equipment |
24,493 |
24,364 | ||||
Less: Accumulated depreciation, depletion and amortization |
(18,002) |
(16,821) | ||||
Total property and equipment, net |
6,491 |
7,543 | ||||
Other long-term assets |
143 |
150 | ||||
Total assets |
8,518 |
8,086 | ||||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
478 |
707 | ||||
Long-term debt |
6,442 |
4,704 | ||||
Deferred income taxes |
2 |
– | ||||
Other long-term liabilities |
448 |
393 | ||||
Total liabilities |
7,370 |
5,804 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 389,673,678 shares as of March 31, 2016 (does not include 3,024,737 shares declared as a stock dividend on March 16, 2016 and issued on April 15, 2016) and 390,138,549 as of December 31, 2015 |
4 |
4 | ||||
Preferred stock, $0.01 par value,10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of March 31, 2016 and December 31, 2015, conversion in January 2018 |
– |
– | ||||
Additional paid-in capital |
3,403 |
3,409 | ||||
Accumulated deficit |
(2,214) |
(1,082) | ||||
Accumulated other comprehensive loss |
(44) |
(48) | ||||
Common stock in treasury; 31,269 shares as of March 31, 2016 and 47,149 as of December 31, 2015, respectively |
(1) |
(1) | ||||
Total equity |
1,148 |
2,282 | ||||
Total liabilities and equity |
$ |
8,518 |
$ |
8,086 |
STATEMENTS OF CASH FLOWS (Unaudited) |
Page 4 of 5 | |||||
Southwestern Energy Company and Subsidiaries |
||||||
For the three months ended | ||||||
March 31, | ||||||
2016 |
2015 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities |
||||||
Net income (loss) |
$ |
(1,132) |
$ |
78 | ||
Adjustments to reconcile net income to net cash provided by operating |
||||||
Depreciation, depletion and amortization |
143 |
293 | ||||
Impairment of natural gas and oil properties |
1,034 |
– | ||||
Amortization of debt issuance costs |
2 |
46 | ||||
Deferred income taxes |
1 |
49 | ||||
Loss on derivatives, net of settlement |
21 |
21 | ||||
Stock-based compensation |
9 |
6 | ||||
Restructuring charges |
42 |
– | ||||
Other |
5 |
– | ||||
Change in assets and liabilities |
(33) |
48 | ||||
Net cash provided by operating activities |
92 |
541 | ||||
Cash Flows From Investing Activities |
||||||
Capital investments |
(196) |
(508) | ||||
Acquisitions |
– |
(591) | ||||
Proceeds from sale of property and equipment |
– |
1 | ||||
Other |
– |
3 | ||||
Net cash used in investing activities |
(196) |
(1,095) | ||||
Cash Flows From Financing Activities |
||||||
Payments on short-term debt |
– |
(4,500) | ||||
Payments on revolving credit facility |
(864) |
(830) | ||||
Borrowings under revolving credit facility |
2,600 |
1,330 | ||||
Payments on commercial paper |
(242) |
– | ||||
Borrowings under commercial paper |
242 |
– | ||||
Change in bank drafts outstanding |
(19) |
(7) | ||||
Proceeds from issuance of long-term debt |
– |
2,200 | ||||
Debt issuance costs |
– |
(17) | ||||
Proceeds from issuance of common stock |
– |
669 | ||||
Proceeds from issuance of mandatory convertible preferred stock |
– |
1,673 | ||||
Preferred stock dividend |
(27) |
– | ||||
Other |
(4) |
– | ||||
Net cash provided by financing activities |
1,686 |
518 | ||||
Increase (decrease) in cash and cash equivalents |
1,582 |
(36) | ||||
Cash and cash equivalents at beginning of year |
15 |
53 | ||||
Cash and cash equivalents at end of period |
$ |
1,597 |
$ |
17 |
SEGMENT INFORMATION (Unaudited) |
Page 5 of 5 | ||||||||||||||
Southwestern Energy Company and Subsidiaries |
Exploration |
||||||||||||||
and |
Midstream |
||||||||||||||
Production |
Services |
Other |
Eliminations |
Total | |||||||||||
(in millions) | |||||||||||||||
Three months ended March 31, 2016 |
|||||||||||||||
Revenues |
$ |
336 |
$ |
621 |
$ |
– |
$ |
(378) |
$ |
579 | |||||
Marketing purchases |
– |
503 |
– |
(307) |
196 | ||||||||||
Operating expenses |
209 |
27 |
– |
(71) |
165 | ||||||||||
General and administrative expenses |
45 |
9 |
– |
– |
54 | ||||||||||
Restructuring charges |
61 |
3 |
– |
– |
64 | ||||||||||
Depreciation, depletion and amortization |
127 |
16 |
– |
– |
143 | ||||||||||
Impairment of natural gas and oil properties |
1,034 |
– |
– |
– |
1,034 | ||||||||||
Taxes, other than income taxes |
20 |
3 |
– |
– |
23 | ||||||||||
Operating income (loss) |
(1,160) |
(1) |
60 |
(2) |
– |
– |
(1,100) | ||||||||
Capital investments(3) |
120 |
2 |
– |
– |
122 | ||||||||||
Three months ended March 31, 2015 |
|||||||||||||||
Revenues |
$ |
655 |
$ |
938 |
$ |
1 |
$ |
(661) |
$ |
933 | |||||
Marketing purchases |
– |
786 |
– |
(564) |
222 | ||||||||||
Operating expenses |
216 |
36 |
– |
(97) |
155 | ||||||||||
General and administrative expenses |
56 |
11 |
1 |
– |
68 | ||||||||||
Depreciation, depletion and amortization |
278 |
15 |
– |
– |
293 | ||||||||||
Taxes, other than income taxes |
27 |
2 |
1 |
– |
30 | ||||||||||
Operating income (loss) |
78 |
88 |
(1) |
– |
165 | ||||||||||
Capital investments(3) |
1,030 |
138 |
3 |
– |
1,171 | ||||||||||
(1) Operating income (loss) for the E&P segment includes $61 million related to restructuring charges. | |||||||||||||||
(2) Operating income (loss) for the Midstream segment includes $3 million related to restructuring charges. | |||||||||||||||
(3) Capital investments includes a $78 million decrease and an immaterial increase for the three months ended March 31, 2016 and 2015, respectively, relating to the change in accrued expenditures between periods. E&P capital for the three months ended March 31, 2015 includes approximately $534 million related to the WPX Property and Statoil Property Acquisitions. Midstream capital for the three months ended March 31, 2015 includes approximately $119 million of firm transport associated with the WPX Property Acquisition. |
SOURCE Southwestern Energy Company
HOUSTON, April 11, 2016 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2016 First Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, April 22, 2016, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's First Quarter 2016 Earnings |
When: |
April 22, 2016 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, April 11, 2016 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2016 First Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, April 22, 2016, at 10:00 a.m. EDT with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's First Quarter 2016 Earnings |
When: |
April 22, 2016 @ 10:00 a.m. EDT |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, March 16, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced that an authorized committee of its Board of Directors declared a quarterly dividend of $15.625 per share on its 6.25% Series B Mandatory Convertible Preferred Stock, payable on April 15, 2016, to holders of record on April 1, 2016. This equates to $0.78125 for each depositary share, which represents a 1/20th interest in a share of the Series B preferred stock. The dividend is for the period beginning on January 15, 2016 and ending on April 14, 2016.
The company has elected to pay this dividend in shares of common stock of the company to the extent permitted by the certificate of designations for the Series B preferred stock. Common shares issued will be listed and tradable on the New York Stock Exchange.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.swn.com.
SOURCE Southwestern Energy Company
HOUSTON, Feb. 25, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today announced its financial and operating results for the fourth quarter and the year ended December 31, 2015. Calendar year 2015 highlights include:
"Our results in the fourth quarter and for the full year 2015 reflect our ability to maneuver through the challenging market conditions facing our entire industry. They also demonstrate the actions we are taking to proactively address the challenges of the current environment to position our company for future success," remarked Bill Way, President and Chief Executive Officer of Southwestern Energy.
"We remained flexible throughout 2015 and, accordingly, we reduced activity to align with market realities and focused on maintaining a strong liquidity position," Way added. "We will continue to optimize our performance by focusing on our core assets and operating efficiently, while we take appropriate actions to position Southwestern to outperform when the pricing environment improves."
The Company's emphasis on capital efficiency was exhibited in 2015 as a higher percentage of the capital program was invested in the higher return Appalachian Basin. Production in Northeast Appalachia grew by 42% and the newly acquired acreage in Southwest Appalachia produced 143 Bcfe in its first year in the Company's portfolio.
Fourth Quarter of 2015 Financial Results
For the fourth quarter of 2015, Southwestern reported an adjusted net loss attributable to common stock of $6 million, or $0.02 per share (reconciled below), when excluding a non-cash ceiling test impairment of natural gas and oil properties of $2.6 billion ($1.6 billion net of taxes) and certain other items typically excluded by the investment community in published estimates, which in aggregate decreased net income by $2.1 billion or $5.56 per share (diluted). Including these items, the net loss attributable to common stock for the fourth quarter of 2015 was $2.1 billion, or $5.58 per share. For the fourth quarter of 2014, Southwestern reported adjusted net income attributable to common stock of $185 million, or $0.52 per diluted share (reconciled below), when excluding a $138 million ($84 million net of taxes) gain on derivative contracts that have not been settled, discrete income tax adjustments totaling $46 million and $5 million ($3 million net of taxes) of certain transaction costs associated with the West Virginia and southwest Pennsylvania acquisition closed in the fourth quarter of 2014. Including these items, net income for the fourth quarter of 2014 was $312 million, or $0.88 per diluted share.
Net cash provided by operating activities before changes in operating assets and liabilities (reconciled below) was $306 million for the fourth quarter of 2015, compared to $570 million for the same period in 2014. On a GAAP basis, net cash provided by operating activities was $353 million for the fourth quarter of 2015, compared to $561 million in the fourth quarter of 2014.
The fourth quarter of 2014 included the operating results from the Company's gathering system in northeast Pennsylvania and its conventional E&P assets in East Texas and the Arkoma basin which were divested during the second quarter of 2015. See "Divestitures" below for additional information.
E&P Segment – The operating loss from the Company's E&P segment was $64 million for the fourth quarter of 2015 (reconciled below), when excluding the non-cash impairment and gain on sale of assets, compared to operating income of $196 million for the same period in 2014. The decrease was primarily due to lower realized natural gas prices and increased operating costs and expenses associated with higher production levels, partially offset by the revenue impacts of these higher production volumes. On a GAAP basis, the operating loss from the Company's E&P segment was $2.6 billion for the fourth quarter of 2015, down from operating income of $196 million during the fourth quarter of 2014.
Net production totaled 249 Bcfe in the fourth quarter of 2015, up 24% from 201 Bcfe in the fourth quarter of 2014. The quarter included 112 Bcf from the Fayetteville Shale, 97 Bcf from Northeast Appalachia and 40 Bcfe from Southwest Appalachia. This compares to 125 Bcf from the Fayetteville Shale and 69 Bcf from Northeast Appalachia and 3 Bcfe from Southwest Appalachia in the fourth quarter of 2014.
Including the effect of hedges, Southwestern's average realized gas price in the fourth quarter of 2015 was $2.07 per Mcf, down from $3.52 per Mcf in the fourth quarter of 2014. The Company's commodity hedging activities increased its average realized gas price by $0.59 per Mcf during the fourth quarter of 2015, compared to an increase of $0.26 per Mcf during the same period in 2014. As of February 23, 2016, the Company had 37 Bcf of its 2016 production hedged at an average price of $2.60 per Mcf. The Company is currently looking to opportunistically add additional hedges to protect the balance sheet while minimizing the loss of any potential benefit associated with a commodity price recovery.
Similar to most producers, the Company typically sells its natural gas at a discount to NYMEX settlement prices. This discount includes basis differential, third-party transportation charges and fuel expenses. Disregarding the impact of hedges, the Company's average price received for its gas production during the fourth quarter of 2015 was approximately $0.79 per Mcf lower than average NYMEX settlement prices, compared to approximately $0.74 per Mcf lower during the fourth quarter of 2014. As of December 31, 2015, we have attempted to mitigate the volatility of basis differentials by protecting basis on approximately 216 Bcf and 67 Bcf of our 2016 and 2017 production, respectively, and expected natural gas production through physical sales arrangements at a basis differential to NYMEX natural gas prices of approximately ($0.16) per Mcf and ($0.20) per Mcf for 2016 and 2017, respectively. Additionally, we have financial hedges in place on 5 Bcf of our 2016 production at a weighted average basis differential of $0.75 per Mcf.
Lease operating expenses per unit of production for the Company's E&P segment were $0.91 per Mcfe in the fourth quarter of 2015, compared to $0.90 per Mcfe in the fourth quarter of 2014. The increase was primarily due to higher operating costs in Southwest Appalachia associated with liquids production.
General and administrative expenses per unit of production were $0.20 per Mcfe in the fourth quarter of 2015, compared to $0.24 per Mcfe in the fourth quarter of 2014, down primarily due to the increase in production volumes.
Taxes other than income taxes were $0.09 per Mcfe in the fourth quarter of 2015 compared to $0.10 per Mcfe for the same period of 2014. Taxes other than income taxes per Mcfe vary from period to period due to changes in severance and ad valorem taxes that result from the mix of the Company's production volumes and fluctuations in commodity prices.
The Company's full cost pool amortization rate decreased to $0.78 per Mcfe in the fourth quarter of 2015, down from $1.12 per Mcfe in the fourth quarter of 2014. The amortization rate is impacted by the timing and amount of reserve additions and the costs associated with those additions, revisions of previous reserve estimates due to both price and well performance, write-downs that result from full cost ceiling tests, proceeds from the sale of properties that reduce the full cost pool and the levels of costs subject to amortization. The Company cannot predict its future full cost pool amortization rate with accuracy due to the variability of each of the factors discussed above, as well as other factors.
Midstream Services – Operating income for the Company's Midstream Services segment, which is comprised of gathering and marketing activities, was $72 million for the fourth quarter of 2015, down 19% from $89 million for the same period in 2014. The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale and the sale of the Company's northeast Pennsylvania gathering assets. At December 31, 2015, the Company's midstream segment was gathering approximately 1.9 Bcf per day through 2,044 miles of gathering lines in the Fayetteville Shale.
Full-Year 2015 Financial Results
For 2015, Southwestern reported adjusted net income attributable to common stock, which includes a $13 million impact from a theoretical income allocation to preferred stock, of $71 million, or $0.19 per diluted share (reconciled below), when excluding a non-cash ceiling test impairment of natural gas and oil properties of $7.0 billion ($4.3 billion net of taxes) and certain other items typically excluded by the investment community in published estimates, which in aggregate decreased net income by $4.7 billion, or $12.47 per share (diluted). Including these items, the net loss attributable to common stock for 2015 was $4.7 billion, or $12.25 per diluted share. For 2014, Southwestern reported adjusted net income attributable to common stock of $801 million, or $2.27 per diluted share (reconciled below), when excluding a $131 million ($80 million net of taxes) gain on derivative contracts that have not been settled, discrete income tax adjustments totaling $46 million and $5 million ($3 million net of taxes) of certain transaction costs associated with the West Virginia and southwest Pennsylvania acquisition closed in the fourth quarter of 2014. Including these items, net income for 2014 was $924 million, or $2.62 per diluted share.
Net cash provided by operating activities before changes in operating assets and liabilities (reconciled below) was $1.5 billion for 2015, compared to $2.3 billion in 2014. On a GAAP basis, net cash provided by operating activities was $1.6 billion for 2015, compared to $2.3 billion for 2014.
E&P Segment – The operating loss from Southwestern's E&P segment was $159 million for 2015 (reconciled below), when excluding the non-cash impairment, gain on sale of assets and restructuring costs, compared to operating income of $1,013 million for 2014. The decrease was primarily due to lower realized natural gas prices and increased operating costs and expenses from higher activity levels, partially offset by the revenue impacts of higher production volumes. On a GAAP basis, the operating loss from the Company's E&P segment was $7.1 billion for 2015, down from operating income of $1.0 billion during 2014.
Net production totaled 976 Bcfe in 2015, up 27% from 768 Bcfe in 2014, and included 465 Bcf from the Fayetteville Shale, 360 Bcf from Northeast Appalachia and 143 Bcfe from Southwest Appalachia. This compares to 494 Bcf from the Fayetteville Shale, 254 Bcf from Northeast Appalachia and 3 Bcfe from Southwest Appalachia in 2014.
Including the effect of hedges, Southwestern's average realized gas price in 2015 was $2.37 per Mcf, down from $3.72 per Mcf in 2014. The Company's commodity hedging activities increased its average realized gas price by $0.46 per Mcf during 2015, compared to a decrease of $0.02 per Mcf during 2014. Disregarding the impact of hedges, the average price received for the Company's gas production during 2015 was approximately $0.75 per Mcf lower than average monthly NYMEX settlement prices, compared to approximately $0.67 per Mcf during 2014.
Lease operating expenses per unit of production for the Company's E&P segment were $0.92 per Mcfe in 2015, compared to $0.91 per Mcfe in 2014. The increase was primarily due to higher operating costs in Southwest Appalachia associated with liquids production.
General and administrative expenses per unit of production were $0.21 per Mcfe in 2015, compared to $0.24 per Mcfe in 2014, down primarily due to the increase in production volumes.
Taxes other than income taxes were $0.10 per Mcfe during 2015, compared to $0.11 per Mcfe in 2014.
The Company's full cost pool amortization rate decreased to $1.00 per Mcfe in 2015, compared to $1.10 per Mcfe in 2014.
Midstream Services – Operating income, excluding the gain on sale of assets divested, for the Company's Midstream Services segment was $306 million for 2015, down 15% from $361 million for 2014 (reconciled below). The decrease in operating income was largely due to a decrease in volumes gathered resulting from lower production volumes in the Fayetteville Shale and the sale of the Company's northeast Pennsylvania gathering assets. On a GAAP basis, operating income for the Midstream Services segment was $583 million for 2015, compared to $361 million for 2014.
Capital Structure and Investments – At December 31, 2015, Southwestern had approximately $4.7 billion in long-term debt, including $116 million borrowed on its revolving credit facility, which is unsecured and matures in December 2018. At December 31, 2015, the Company had strong liquidity with almost $1.9 billion available capacity, no significant debt maturities prior to 2018 and an operating plan that aligns the Company's capital investment program with the cash flows generated from its operations. The Company's long-term debt ratings are BB+ by Standard and Poor's, B1 by Moody's and BBB- by Fitch. These ratings result in current interest rates under the revolving credit facility and the $750 million term loan of 2.00% and 1.625% over LIBOR, respectively.
During 2015, excluding the $609 million of acquisition costs and post-closing adjustments for the Appalachia transactions that closed in December 2014 and January 2015, Southwestern invested a total of $1.8 billion. This included approximately $1.8 billion invested in its E&P business, $58 million invested in its Midstream Services segment and $12 million invested for corporate and other purposes. The Company exhibited flexibility in twice adjusting its capital investment levels in 2015 to align with the decreasing commodity prices, lowering capital investments by 30% from its original 2015 plan.
Divestitures
The Company divested its gathering system in northeast Pennsylvania and its conventional E&P assets in East Texas and the Arkoma basin in the second quarter of 2015.
The northeast Pennsylvania gathering system generated operating income of $13 million in 2015, compared to operating income of $8 million and $35 million for the three and twelve months ended December 31, 2014. For 2015, this gathering system generated net cash provided by operating activities of $15 million. For the three and twelve months ended December 31, 2014, this gathering system generated net cash provided by operating activities of approximately $10 million and $42 million, respectively.
The conventional E&P assets in East Texas and the Arkoma basin had production of 6 Bcfe during 2015. This compares to 4 Bcfe and 15 Bcfe for the three and twelve months ended December 31, 2014, respectively. These assets generated operating income of $3 million and $27 million for the three and twelve months ended December 31, 2014, respectively.
2015 Natural Gas and Oil Reserves and Operational Review
Southwestern's estimated proved natural gas and oil reserves totaled approximately 6,215 Bcfe at December 31, 2015, compared to 10,747 Bcfe at the end of 2014. The decrease in the Company's reserves in 2015 was primarily due to downward price revisions in its proved undeveloped reserves associated with decreased commodity prices, partially offset by upward performance revisions in Northeast Appalachia and Southwest Appalachia and the Company's successful development programs in the Northeast Appalachia, Southwest Appalachia and the Fayetteville Shale. The average prices utilized to value the Company's estimated proved natural gas and oil reserves at December 31, 2015 were $2.59 per MMBtu for natural gas, $46.79 per barrel for oil and $6.82 per barrel for NGLs, compared to $4.35 per MMBtu for natural gas, $91.48 per barrel for oil and $23.79 per barrel for NGLs at December 31, 2014. Approximately 95% of the Company's estimated proved reserves were natural gas and 93% were classified as proved developed at year-end 2015, compared to 91% and 55%, respectively, at year-end 2014.
The following table details additional information relating to reserve estimates as of and for the year ended December 31, 2015:
Natural Gas |
Oil |
NGL |
Total |
|||||
(Bcf) |
(MBbls) |
(MBbls) |
(Bcfe) |
|||||
Proved reserves, beginning of year |
9,809 |
37,615 |
118,699 |
10,747 |
||||
Revisions of previous estimates |
(3,458) |
(28,394) |
(75,664) |
(4,083) |
||||
Extensions, discoveries and other additions |
546 |
1,367 |
6,274 |
592 |
||||
Production |
(899) |
(2,265) |
(10,702) |
(976) |
||||
Acquisition of reserves in place |
97 |
525 |
2,340 |
114 |
||||
Disposition of reserves in place |
(178) |
(95) |
– |
(179) |
||||
Proved reserves, end of year |
5,917 |
8,753 |
40,947 |
6,215 |
||||
Proved developed reserves: |
||||||||
Beginning of year |
5,675 |
7,445 |
38,632 |
5,951 |
||||
End of year |
5,474 |
8,753 |
40,947 |
5,772 |
Note: Figures may not add due to rounding |
In 2015, the Company's reserve replacement ratio was negatively affected by net downward revisions of 4,083 Bcfe primarily as a result of the depressed commodity price environment. The Company's production volumes were partially offset with 592 Bcfe of proved reserve additions and 114 Bcfe of proved reserve additions as a result of acquisitions. Of the reserve additions, 416 Bcfe were proved developed and 176 Bcfe were proved undeveloped. In 2015, downward reserve revisions resulting from lower natural gas, oil and NGL prices totaled 2,315 Bcf, 1,875 Bcfe, 1,496 Bcf and 32 Bcfe in our Northeast Appalachia, Southwest Appalachia, Fayetteville Shale and other divisions, respectively. Southwestern also had upward performance revisions in 2015 of 1,383 Bcf, 209 Bcfe, 10 Bcf and 33 Bcfe in its Northeast Appalachia, Southwest Appalachia, Fayetteville Shale and other divisions, respectively. Additionally, our reserves decreased by 179 Bcfe as a result of our sale of natural gas and oil leases and wells in 2015. Excluding price revisions, 240% of the Company's production volumes were replaced with proved reserve additions, acquisitions and performance revisions. For the period ending December 31, 2015, the Company's three-year average reserve replacement ratio, including revisions and acquisitions, was 199%. Excluding reserve revisions and acquisitions, the Company's three-year average reserve replacement ratio was 232%.
The Company's 2015 and three-year average finding and development costs, including performance revisions, were $0.61 and $0.62 per Mcfe, respectively, when excluding price revisions, acquisitions and the impact of capitalizing interest and portions of G&A costs in accordance with the full cost method of accounting (a non-GAAP financial measure computed below). Including price revisions, acquisitions and the impact of capitalizing interest and portions of G&A costs in accordance with the full cost method of accounting, the Company's three-year average finding and development costs for the period ending December 31, 2015 was $2.40 per Mcfe.
The following table provides an overall and by category summary of the Company's natural gas, oil and NGL reserves as of December 31, 2015 and sets forth 2015 annual information related to production and capital investments for each of its operating areas:
2015 PROVED RESERVES BY CATEGORY AND SUMMARY OPERATING DATA | ||||||||||||||
Appalachia |
||||||||||||||
Northeast |
Southwest |
Fayetteville Shale |
Other (1) |
Total | ||||||||||
Estimated Proved Reserves: |
||||||||||||||
Natural Gas (Bcf): |
||||||||||||||
Developed (Bcf) |
2,005 |
311 |
3,156 |
2 |
5,474 | |||||||||
Undeveloped (Bcf) |
314 |
4 |
125 |
– |
443 | |||||||||
2,319 |
315 |
3,281 |
2 |
5,917 | ||||||||||
Crude Oil (MMBbls): |
||||||||||||||
Developed (MMBbls) |
– |
8.5 |
– |
0.3 |
8.8 | |||||||||
Undeveloped (MMBbls) |
– |
– |
– |
– |
– | |||||||||
– |
8.5 |
– |
0.3 |
8.8 | ||||||||||
Natural Gas Liquids (MMBbls): |
||||||||||||||
Developed (MMBbls) |
– |
40.9 |
– |
– |
40.9 | |||||||||
Undeveloped (MMBbls) |
– |
– |
– |
– |
– | |||||||||
– |
40.9 |
– |
– |
40.9 | ||||||||||
Total Proved Reserves (Bcfe)(2): |
||||||||||||||
Developed (Bcfe) |
2,005 |
607 |
3,156 |
4 |
5,772 | |||||||||
Undeveloped (Bcfe) |
314 |
4 |
125 |
– |
443 | |||||||||
2,319 |
611 |
3,281 |
4 |
6,215 | ||||||||||
Percent of Total |
37% |
10% |
53% |
0% |
100% | |||||||||
Percent Proved Developed |
86% |
99% |
96% |
100% |
93% | |||||||||
Percent Proved Undeveloped |
14% |
1% |
4% |
0% |
7% | |||||||||
Production (Bcfe) |
360 |
143 |
465 |
8 |
976 | |||||||||
Capital Investments (millions)(3) |
$ |
710 |
$ |
857 |
$ |
565 |
$ |
105 |
$ |
2,237 | ||||
Total Gross Producing Wells(4) |
774 |
1,085 |
4,268 |
20 |
6,147 | |||||||||
Total Net Producing Wells(4) |
407 |
859 |
2,971 |
17 |
4,254 | |||||||||
Total Net Acreage |
270,335 |
(5) |
425,098 |
(6) |
957,641 |
(7) |
3,673,853 |
(8) |
5,326,927 | |||||
Net Undeveloped Acreage |
168,753 |
(5) |
193,582 |
(6) |
288,569 |
(7) |
3,661,375 |
(8) |
4,312,279 | |||||
PV-10: |
||||||||||||||
Pre-Tax (millions)(9) |
$ |
707 |
$ |
115 |
$ |
1,604 |
$ |
(9) |
$ |
2,417 | ||||
PV of Taxes (millions)(9) |
– |
– |
– |
– |
– | |||||||||
After-Tax (millions)(9) |
$ |
707 |
$ |
115 |
$ |
1,604 |
$ |
(9) |
$ |
2,417 | ||||
Percent of Total |
29% |
5% |
66% |
0% |
100% | |||||||||
Percent Operated(10) |
98% |
95% |
99% |
100% |
98% |
(1) |
Other includes New Ventures and the production from Southwestern's Ark-La-Tex properties divested in May 2015. |
(2) |
There are no reserves from synthetic gas, synthetic oil or nonrenewable natural resources intended to be upgraded into synthetic gas or oil. The Company used standard engineering and geoscience methods, or a combination of methodologies in determining estimates of material properties, including performance and test date analysis offset statistical analogy of performance data, volumetric evaluation, including analysis of petrophysical parameters (including porosity, net pay, fluid saturations (i.e., water, oil and gas) and permeability) in combination with estimated reservoir parameters (including reservoir temperature and pressure, formation depth and formation volume factors), geological analysis, including structure and isopach maps and seismic analysis, including review of 2-D and 3-D data to ascertain faults, closure and other factors. |
(3) |
The Total and Fayetteville Shale capital investments exclude $21 million related to the Company's drilling rig related equipment, sand facility and other equipment. |
(4) |
Represents all producing wells, including wells in which the Company only has an overriding royalty interest, as of December 31, 2015. |
(5) |
Assuming successful wells are not drilled to develop the acreage and leases are not extended, leasehold expiring over the next three years will be 30,172 net acres in 2016, 57,724 net acres in 2017 and 12,891 net acres in 2018. |
(6) |
Assuming successful wells are not drilled to develop the acreage and leases are not extended leasehold expiring over the next three years will be 36,934 net acres in 2016, 42,034 net acres in 2017 and 12,604 net acres in 2018. Of this acreage, 16,160 net acres in 2016, 15,262 net acres in 2017 and 1,990 net acres in 2018 can be extended for an average of an additional 4.8 years. |
(7) |
The Fayetteville Shale acreage includes 31,413 net undeveloped acres and 170,743 net developed acres in the Arkoma Basin that have previously been reported as a component of conventional Arkoma acreage. Assuming successful wells are not drilled to develop the acreage and leases are not extended, leasehold expiring over the next three years will be 164 net acres in 2016, 453 net acres in 2017 and 31 net acres in 2018 (excluding 158,231 net acres held on federal lands which are currently suspended by the Bureau of Land Management). |
(8) |
Assuming successful wells are not drilled to develop the acreage and leases are not extended, the Company's leasehold expiring over the next three years, excluding New Brunswick, Canada, the Lower Smackover Brown Dense area and the Sand Wash Basin, will be 255,527 net acres in 2016, 217,927 net acres in 2017 and 23,086 net acres in 2018. With regard to the Company's acreage in New Brunswick, Canada, exploration licenses were extended through 2021. With regard to acreage in the Lower Smackover Brown Dense, assuming successful wells are not drilled and leases are not extended, leasehold expiring over the next three years will be 58,849 net acres in 2016, 68,790 net acres in 2017 and 67,528 net acres in 2018. With regard to acreage in the Sand Wash Basin, assuming successful wells are not drilled and leases are not extended, leasehold expiring over the next three years will be 85,767 net acres in 2016, 35,883 net acres in 2017, and 55,918 net acres in 2018. |
(9) |
Pre-tax PV-10 (a non-GAAP measure) is one measure of the value of a Company's proved reserves that the Company believes is used by securities analysts to compare relative values among peer companies without regard to income taxes. The reconciling difference in pre-tax PV-10 and the after-tax PV-10, or standardized measure, is the discounted value of future income taxes on the estimated cash flows from the Company's proved natural gas, oil and NGL reserves. |
(10) |
Based upon pre-tax PV-10 of proved developed producing activities. |
During 2015, Southwestern invested a total of $1.8 billion in its E&P business, excluding acquisition costs and post-closing adjustments for the Appalachia transactions that closed in December 2014 and January 2015 of $609 million, which included $500 million related to the Company's E&P business and $109 million to Midstream Services. The Company participated in drilling 576 wells, placed 430 wells to sales, and had 203 wells which were in progress at year-end. Of the 203 wells in progress at year-end, 83, 43 and 77 were located in its Northeast Appalachia, Southwest Appalachia and Fayetteville Shale, respectively. Of the $1.8 billion invested in the Company's E&P business in 2015, $547 million was invested in Northeast Appalachia, $520 million in Southwest Appalachia, $565 million in the Fayetteville Shale, $102 million in New Ventures and $21 million in E&P services.
Excluding the acquisitions announced in the fourth quarter of 2014, of the $1.8 billion invested in 2015, $1.2 billion was invested in exploratory and development drilling and workovers, $390 million in capitalized interest and other expenses, $107 million for acquisition of properties, and $6 million for seismic expenditures. Additionally, the Company invested $21 million in its drilling rig related equipment, sand facility and other equipment.
Northeast Appalachia – In 2015, Southwestern invested $710 million in Northeast Appalachia, which included $472 million to spud 89 operated wells and acquire 86 horizontal and 2 vertical wells. Total capital investments in Northeast Appalachia during 2015 also included $172 million for the acquisition of properties and $66 million in facilities, capitalized costs and other expenses.
Southwestern's net gas production from Northeast Appalachia was 360 Bcf in 2015, up 42% from 254 Bcf in 2014. Gross operated production in Northeast Appalachia was 1,302 MMcf per day at the end of 2015 compared to approximately 1,020 MMcf per day at the end of 2014.
Total proved reserves in Northeast Appalachia were 2,319 Bcf as of December 31, 2015, compared to 3,192 Bcf at year-end 2014. The net decrease in reserves included downward price revisions of 2,315 Bcf and production of 360 Bcf, partially offset by upward reserve revisions due to well performance of 1,383 Bcf, reserve additions of 340 Bcf and acquisitions of 79 Bcf. The average gross proved reserves for the 36 undeveloped locations included in the Company's 2015 year-end reserves was approximately 10.4 Bcf per well, compared to 9.6 Bcf per well for the 200 undeveloped locations as of December 2014.
In the fourth quarter of 2015, the average 30th-day rate was 5,601 Mcf per day on 33 wells that had an average lateral length of 5,429 feet and an average cost of $4.9 million per well. This compares to an average 30th-day rate of 5,720 Mcf per day on 19 wells that had an average lateral length of 5,512 feet and an average cost of $5.5 million per well in the third quarter of 2015. In 2015, for wells online with a 30th-day rate, Southwestern's operated horizontal wells had an average completed well cost of $5.6 million per well and an average horizontal lateral length of 5,384 feet. This compares to an average completed operated well cost of $6.1 million per well and an average horizontal lateral length of 4,752 feet in 2014.
As of December 31, 2015, Southwestern had spud or acquired 553 operated wells, of which 423 were horizontal and on production and 83 were in progress. Of the 423 operated horizontal wells on production, 139 were located in Bradford County, 25 were located in Lycoming County and 259 were located in Susquehanna County. Of the 83 wells in progress, 35 were either waiting on completion or waiting to be placed to sales, including 25 in Susquehanna County, 6 in Bradford County and 4 wells in Sullivan, Tioga and Wyoming Counties, combined.
The graph below provides normalized average daily production data through December 31, 2015, for the horizontal wells drilled by the Company in Northeast Appalachia. The "pink curve" summarizes results for 139 wells in Bradford County, the "blue curve" reflects results for 259 wells in Susquehanna County, the "orange curve" shows the results for 25 wells in Lycoming County and the "green curve" averages the results for the 146 wells that have been put on production within the last 18 months. As a reminder, the pressure drawdown in the reservoir, hence the production rates from all of the wells in Northeast Appalachia, are managed to maximize the ultimate recovery from the wells. The impact of this program is exhibited in all of the curves with the relatively flat production for the first 365 days before the wells begin normal declines. Furthermore, the Company continues to improve its completion design, and the performance history from the most recent wells is beginning to reflect these improvements. The normalized production curves are intended to provide a qualitative indication of the Company's Northeast Appalachia wells' performance and should not be used to estimate an individual well's estimated ultimate recovery. The 8, 10 and 12 Bcf type curves are shown solely for reference purposes and are not intended to be projections of the performance of the Company's wells.
At December 31, 2015, Southwestern held leases for approximately 270,335 net acres in Northeast Appalachia, compared to approximately 266,073 net acres at year-end 2014.
Southwest Appalachia – In 2015, Southwestern invested $857 million in Southwest Appalachia, which included $248 million to spud 48 operated wells. Total capital investments in Southwest Appalachia during 2015 also included $409 million for the acquisition of properties and $200 million in capitalized costs and other expenses. Net production from Southwest Appalachia was 143 Bcfe in 2015.
Total proved reserves in Southwest Appalachia were 611 Bcfe at year-end 2015, compared to 2,297 Bcfe in 2014. The net decrease in reserves included downward price revisions of 1,875 Bcfe and production of 143 Bcfe, partially offset by upward reserve revisions due to well performance of 209 Bcfe, reserve additions of 88 Bcfe and acquisitions of 35 Bcfe.
In 2015, the Company drilled 48 wells, with an average lateral length of 6,544 feet and average time to drill to total depth of 17.6 days from re-entry to re-entry. Additionally, Southwestern placed 47 wells on production. The Company again achieved better results by drilling in a tighter target interval, enhancing the completion design and utilizing pressure drawdown management.
For example, the Company placed 4 horizontal wells on production in Wetzel County where the average estimated ultimate recovery per 1,000 lateral feet was 2.9 Bcfe, or 95% higher than the offset wells drilled and completed by the previous operator, when normalized for lateral length. Another example is the Alice Edge pad, where 9 wells were brought online during the fourth quarter. These wells combined for over 86,000 feet of completed lateral length and exhibited very strong performance with the pad having a peak rate of almost 50 million cubic feet per day of gas production and over 5 thousand barrels per day of condensate production. Results from all of the wells brought online are shown in the table below.
Time Frame |
Wells Placed on Production |
Average Lateral Length |
Avg Rate
For 1st 30 Days (Mcfe/d) (# of wells) |
30th-Day
% Gas / Condensate / NGL |
Avg Rate
For 1st 60 Days (Mcfe/d) (# of wells) |
60th-Day
% Gas / Condensate / NGL |
2nd Qtr 2015 |
10 |
5,399 |
6,428 (10) |
51 / 13 / 36 |
6,246 (10) |
52 / 11 / 37 |
3rd Qtr 2015 |
5 |
5,898 |
6,703 (5) |
37 / 18 / 45 |
7,038 (5) |
38 / 15 / 47 |
4th Qtr 2015 |
19 |
7,833 |
6,810 (19) |
39 / 20 / 41 |
7,864 (15) |
41 / 18 / 41 |
In the fourth quarter of 2015, the Company drilled its first Utica well, the O. E. Burge located in Marshall County, West Virginia. Despite operational challenges being faced similar to other Utica wells in the area, the Company was able to drill the well to its targeted 8,000 feet of lateral length and stayed in the target interval 100% of the time. The Company is encouraged by the data observed during drilling and will report updates as they occur.
The Company had a total of 318 horizontal and 676 vertical wells that the Company operated and that were on production as of December 31, 2015. Additionally, there were 43 horizontal wells in progress at the end of 2015, of which 21 were waiting on pipeline or production facilities.
At December 31, 2015, Southwestern held leases for approximately 425,098 net acres in Southwest Appalachia, compared to approximately 413,376 net acres at year-end 2014.
Fayetteville Shale – In 2015, Southwestern invested $565 million in the Fayetteville Shale, which included $481 million to spud 155 wells, all of which were operated. Total capital investments in the Fayetteville Shale during 2015 also included $4 million for the acquisition of properties and $80 million in capitalized costs and other expenses.
Southwestern's net gas production from the Fayetteville Shale was 465 Bcf in 2015, compared to 494 Bcf in 2014. Gross operated gas production in the Fayetteville Shale was approximately 1,759 MMcf per day at the end of 2015 compared to approximately 2,132 MMcf per day at the end of 2014.
Total proved reserves in the Fayetteville Shale were 3,281 Bcf at year-end 2015, compared to 5,069 Bcf in 2014. The net decrease in reserves included downward price revisions of 1,496 Bcf and production of 465 Bcf, partially offset by reserve additions of 163 Bcf and positive revisions of 10 Bcf due to well performance. A total of 61 undeveloped locations were included in the 2015 year-end reserves at approximately 3.0 Bcf per well, compared to the 1,213 undeveloped locations at approximately 2.3 Bcf per well booked as of December 2014.
Southwestern's operated horizontal wells had an average completed well cost of $2.8 million per well, average horizontal lateral length of 5,729 feet and average time to drill to total depth of 7.3 days from re-entry to re-entry in 2015. This compares to an average completed operated well cost of $2.6 million per well, average horizontal lateral length of 5,440 feet and average time to drill to total depth of 6.8 days from re-entry to re-entry in 2014. Southwestern placed 261 operated wells on production during 2015 with average initial production rates of 4,280 Mcf per day, compared to 454 operated wells with average initial production rates of 4,430 Mcf per day in 2014.
During the fourth quarter of 2015, the Company's horizontal wells had an average initial production rate of 4,277 Mcf per day, average completed well cost of $2.8 million per well, average horizontal lateral length of 5,526 feet and average time to drill to total depth of 8.3 days from re-entry to re-entry. This compares to an average initial production rate of 3,886 Mcf per day, an average horizontal lateral length of 5,407 feet, average time to drill to total depth of 6.9 days from re-entry to re-entry and an average completed well cost of $2.7 million per well in the third quarter of 2015.
At December 31, 2015, Southwestern held leases for approximately 957,641 net acres in the Fayetteville Shale area, compared to approximately 888,161 net acres at year-end 2014. Certain acreage previously reported as a component of Southwestern's conventional Arkoma Basin has been included in the unconventional net acreage for the Fayetteville Shale at December 31, 2015 reflecting the Company's current drilling focus.
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 and the results of its peers and of prior periods. These non-GAAP performance measures often exclude items typically excluded by the investment community in published estimates to improve comparability.
One such non-GAAP financial measure is net cash provided by operating activities before changes in operating assets and liabilities. 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 adjusted net income, adjusted diluted earnings per share, adjusted EBITDA and its E&P and Midstream segment operating income, all which exclude certain charges or amounts. Management presents these measures because (i) they are consistent with the manner in which the Company's performance is measured relative to the performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations below of GAAP financial measures to non-GAAP financial measures for the three and twelve months ended December 31, 2015 and December 31, 2014. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
3 Months Ended Dec 31, | |||
2015 |
2014 | ||
(in millions) | |||
Net income (loss) attributable to common stock: |
|||
Net income (loss) attributable to common stock |
$ (2,134) |
$ 312 | |
Add back (deduct): |
|||
Impairment of natural gas and oil properties (net of taxes) |
1,597 |
- | |
(Gain) Loss on certain derivatives (net of taxes) |
31 |
(84) | |
Adjustments due to discrete tax items(1, 2) |
483 |
(46) | |
Adjustments due to inventory valuation (net of taxes) |
20 |
- | |
Gain on sale of assets (net of taxes) |
(4) |
- | |
Transaction costs (net of taxes) |
1 |
3 | |
Adjusted net income (loss) attributable to common stock |
$ (6) |
$ 185 | |
12 Months Ended Dec 31, | |||
2015 |
2014 | ||
(in millions) | |||
Net income (loss) attributable to common stock: |
|||
Net income (loss) attributable to common stock |
$ (4,662) |
$ 924 | |
Add back (deduct): |
|||
Participating securities – mandatory convertible preferred stock |
(13) |
- | |
Impairment of natural gas and oil properties (net of taxes) |
4,287 |
- | |
(Gain) Loss on certain derivatives (net of taxes) |
96 |
(80) | |
Adjustments due to discrete tax items(1, 2) |
483 |
(46) | |
Adjustments due to inventory valuation (net of taxes) |
20 |
- | |
Gain on sale of assets (net of taxes) |
(174) |
- | |
Transaction costs (net of taxes) |
33 |
3 | |
Restructuring costs (net of taxes) |
1 |
- | |
Adjusted net income attributable to common stock |
$ 71 |
$ 801 | |
3 Months Ended Dec 31, | |||
2015 |
2014 | ||
Diluted earnings per share: |
|||
Diluted earnings per share |
$ (5.58) |
$ 0.88 | |
Add back (deduct): |
|||
Impairment of natural gas and oil properties (net of taxes) |
4.18 |
- | |
(Gain) Loss on certain derivatives (net of taxes) |
0.08 |
(0.24) | |
Adjustments due to discrete tax items(1, 2) |
1.26 |
(0.13) | |
Adjustments due to inventory valuation (net of taxes) |
0.05 |
- | |
Gain on sale of assets (net of taxes) |
(0.01) |
- | |
Transaction costs (net of taxes) |
0.00 |
0.01 | |
Adjusted diluted earnings per share |
$ (0.02) |
$ 0.52 | |
12 Months Ended Dec 31, | |||
2015 |
2014 | ||
Diluted earnings per share: |
|||
Diluted earnings per share |
$ (12.25) |
$ 2.62 | |
Add back (deduct): |
|||
Participating securities – mandatory convertible preferred stock |
(0.03) |
- | |
Impairment of natural gas and oil properties (net of taxes) |
11.27 |
- | |
(Gain) Loss on certain derivatives (net of taxes) |
0.25 |
(0.23) | |
Adjustments due to discrete tax items(1, 2) |
1.27 |
(0.13) | |
Adjustments due to inventory valuation (net of taxes) |
0.05 |
||
Gain on sale of assets (net of taxes) |
(0.46) |
- | |
Transaction costs (net of taxes) |
0.09 |
0.01 | |
Restructuring costs (net of taxes) |
0.00 |
- | |
Adjusted diluted earnings per share |
$ 0.19 |
$ 2.27 | |
3 Months Ended Dec 31, | |||
2015 |
2014 | ||
(in millions) | |||
E&P segment operating income (loss): |
|||
E&P segment operating income (loss) |
$ (2,633) |
$ 196 | |
Add back (deduct): |
|||
Impairment of natural gas and oil properties |
2,576 |
- | |
Gain on sale of assets |
(7) |
- | |
Adjusted E&P segment operating income (loss) |
$ (64) |
$ 196 | |
12 Months Ended Dec 31, | |||
2015 |
2014 | ||
(in millions) | |||
E&P segment operating income (loss): |
|||
E&P segment operating income (loss) |
$ (7,104) |
$ 1,013 | |
Add back (deduct): |
|||
Impairment of natural gas and oil properties |
6,950 |
- | |
Gain on sale of assets |
(6) |
- | |
Restructuring costs |
1 |
- | |
Adjusted E&P segment operating income (loss) |
$ (159) |
$ 1,013 | |
12 Months Ended Dec 31, | |||
2015 |
2014 | ||
(in millions) | |||
Midstream segment operating income: |
|||
Midstream segment operating income |
$ 583 |
$ 361 | |
Add back (deduct): |
|||
Gain on sale of assets |
(277) |
- | |
Adjusted Midstream segment operating income |
$ 306 |
$ 361 | |
3 Months Ended Dec 31, | |||
2015 |
2014 | ||
(in millions) | |||
Cash flow from operating activities: |
|||
Net cash provided by operating activities |
$ 353 |
$ 561 | |
Add back (deduct): |
|||
Changes in operating assets and liabilities |
(47) |
9 | |
Net cash provided by operating activities before changes in operating assets and liabilities |
$ 306 |
$ 570 | |
12 Months Ended Dec 31, | |||
2015 |
2014 | ||
(in millions) | |||
Cash flow from operating activities: |
|||
Net cash provided by operating activities |
$ 1,580 |
$ 2,335 | |
Add back (deduct): |
|||
Changes in operating assets and liabilities |
(112) |
(65) | |
Net cash provided by operating activities before changes in operating assets and liabilities |
$ 1,468 |
$ 2,270 |
(1) |
2015 primarily relates to the exclusion of certain discrete tax adjustments in the fourth quarter of 2015 due to an increase to the valuation allowance against the Company's deferred tax assets. The Company expects its 2016 income tax rate to be 38.0%. |
(2) |
2014 primarily relates to the exclusion of certain discrete tax adjustment that were recognized in the fourth quarter of 2014 due to a redetermination of deferred state tax liabilities to reflect updated state apportionment factors. |
Finding and development costs – Finding and development (F&D) costs are computed by dividing acquisition, exploration and development capital costs incurred for the indicated period by reserve additions, including reserves acquired, for that same period. At times, adjustments are made to this calculation in order to improve usefulness for investors. For example, price revisions are often excluded due to volatile commodity price changes. Another example is the adjustment made to exclude the differences between accounting methods to improve comparability. The following computes F&D costs using information required by GAAP for the periods ending December 31, 2015 and 2014 and the three years ending December 31, 2015. A breakdown is also shown detailing these amounts separately for Northeast Appalachia, Southwest Appalachia and the Fayetteville Shale.
Total Company | |||||
For the 12 Months |
For the 12 Months |
For the 3 Years | |||
Ended |
Ended |
Ended | |||
December 31, 2015 |
December 31, 2014 |
December 31, 2015 | |||
Total exploration, development and acquisition costs incurred ($ in thousands) |
$ 2,240,200 |
$ 7,220,776 |
$ 11,484,254 | ||
Reserve extensions, discoveries and acquisitions (MMcfe) |
706,156 |
3,997,329 |
7,992,469 | ||
Finding & development costs, excluding revisions ($/Mcfe) |
$ 3.17 |
$ 1.81 |
$ 1.44 | ||
Reserve extensions, discoveries, acquisitions and performance revisions (MMcfe) |
2,340,661 |
4,486,406 |
10,195,661 | ||
Finding & development costs, including performance revisions ($/Mcfe) |
$ 0.96 |
$ 1.61 |
$ 1.13 | ||
Total exploration and development costs incurred ($ in thousands) |
$ 1,739,661 |
$ 1,944,245 |
$ 5,611,140 | ||
Reserve extensions, discoveries and performance revisions (MMcfe) |
2,226,267 |
2,182,361 |
7,773,108 | ||
Finding & development costs, excluding price revisions and acquisitions ($/Mcfe) |
$ 0.78 |
$ 0.89 |
$ 0.72 | ||
Total exploration and development costs incurred, excluding the impact of capitalizing interest and portions of G&A ($ in thousands) |
$ 1,360,910 |
$ 1,706,956 |
$ 4,782,801 | ||
Reserve extensions, discoveries and performance revisions (MMcfe) |
2,226,267 |
2,182,361 |
7,773,108 | ||
F&D costs, excluding price revisions, acquisitions and the impact of capitalizing interest and portions of G&A in accordance with full cost accounting ($/Mcfe) |
$ 0.61 |
$ 0.78 |
$ 0.62 |
Northeast Appalachia | ||||||
For the 12 Months |
For the 12 Months |
For the 3 Years | ||||
Ended |
Ended |
Ended | ||||
December 31, 2015 |
December 31, 2014 |
December 31, 2015 | ||||
Total exploration, development and acquisition costs incurred ($ in thousands) |
$ 701,434 |
$ 711,647 |
$ 2,294,078 | |||
Reserve extensions, discoveries and acquisitions (MMcfe) |
419,145 |
836,250 |
2,455,627 | |||
Finding & development costs, excluding revisions ($/Mcfe) |
$ 1.67 |
$ 0.85 |
$ 0.93 | |||
Reserve extensions, discoveries, acquisitions and performance revisions (MMcfe) |
1,802,640 |
1,472,409 |
4,537,470 | |||
Finding & development costs, including performance revisions ($/Mcfe) |
$ 0.39 |
$ 0.48 |
$ 0.51 | |||
Total exploration and development costs incurred ($ in thousands) |
$ 562,103 |
$ 704,012 |
$ 2,051,294 | |||
Reserve extensions, discoveries and performance revisions (MMcfe) |
1,723,323 |
1,470,696 |
4,452,326 | |||
Finding & development costs, excluding price revisions and acquisitions ($/Mcfe) |
$ 0.33 |
$ 0.48 |
$ 0.46 | |||
Total exploration and development costs incurred, excluding the impact of capitalizing interest and portions of G&A ($ in thousands) |
$ 504,196 |
$ 637,676 |
$ 1,866,680 | |||
Reserve extensions, discoveries and performance revisions (MMcfe) |
1,723,323 |
1,470,696 |
4,452,326 | |||
F&D costs, excluding price revisions, acquisitions and the impact of capitalizing interest and portions of G&A in accordance with full cost accounting ($/Mcfe) |
$ 0.29 |
$ 0.43 |
$ 0.42 |
Southwest Appalachia | ||||||
For the 12 Months |
For the 12 Months |
For the 2 Years | ||||
Ended |
Ended |
Ended | ||||
December 31, 2015 |
December 31, 2014 |
December 31, 2015 | ||||
Total exploration, development and acquisition costs incurred ($ in thousands) |
$ 849,790 |
$ 5,051,924 |
$ 5,901,714 | |||
Reserve extensions, discoveries and acquisitions (MMcfe) |
123,409 |
2,300,259 |
2,423,668 | |||
Finding & development costs, excluding revisions ($/Mcfe) |
$ 6.89 |
$ 2.20 |
$ 2.44 | |||
Reserve extensions, discoveries, acquisitions and performance revisions (MMcfe) |
332,195 |
2,300,259 |
2,632,454 | |||
Finding & development costs, including performance revisions ($/Mcfe) |
$ 2.56 |
$ 2.20 |
$ 2.24 | |||
Total exploration and development costs incurred ($ in thousands) |
$ 488,525 |
$ - |
$ 488,525 | |||
Reserve extensions, discoveries and performance revisions (MMcfe) |
297,118 |
- |
297,118 | |||
Finding & development costs, excluding price revisions and acquisitions ($/Mcfe) |
$ 1.64 |
N/A |
$ 1.64 | |||
Total exploration and development costs incurred, excluding the impact of capitalizing interest and portions of G&A ($ in thousands) |
$ 290,751 |
$ - |
$ 290,751 | |||
Reserve extensions, discoveries and performance revisions (MMcfe) |
297,118 |
- |
297,118 | |||
F&D costs, excluding price revisions, acquisitions and the impact of capitalizing interest and portions of G&A in accordance with full cost accounting ($/Mcfe) |
$ 0.98 |
N/A |
$ 0.98 |
Fayetteville Shale | ||||||
For the 12 Months |
For the 12 Months |
For the 3 Years | ||||
Ended |
Ended |
Ended | ||||
December 31, 2015 |
December 31, 2014 |
December 31, 2015 | ||||
Total exploration, development and acquisition costs incurred ($ in thousands) |
$ 578,063 |
$ 972,823 |
$ 2,489,938 | |||
Reserve extensions, discoveries and acquisitions (MMcfe) |
162,871 |
856,307 |
3,105,774 | |||
Finding & development costs, excluding revisions ($/Mcfe) |
$ 3.55 |
$ 1.14 |
$ 0.80 | |||
Reserve extensions, discoveries, acquisitions and performance revisions (MMcfe) |
173,000 |
730,078 |
3,005,984 | |||
Finding & development costs, including performance revisions ($/Mcfe) |
$ 3.34 |
$ 1.33 |
$ 0.83 | |||
Total exploration and development costs incurred ($ in thousands) |
$ 578,063 |
$ 971,425 |
$ 2,488,315 | |||
Reserve extensions, discoveries and performance revisions (MMcfe) |
173,000 |
730,078 |
3,005,984 | |||
Finding & development costs, excluding price revisions and acquisitions ($/Mcfe) |
$ 3.34 |
$ 1.33 |
$ 0.83 | |||
Total exploration and development costs incurred, excluding the impact of capitalizing interest and portions of G&A ($ in thousands) |
$ 509,307 |
$ 876,780 |
$ 2,236,879 | |||
Reserve extensions, discoveries and performance revisions (MMcfe) |
173,000 |
730,078 |
3,005,984 | |||
F&D costs, excluding price revisions, acquisitions and the impact of capitalizing interest and portions of G&A in accordance with full cost accounting ($/Mcfe) |
$ 2.94 |
$ 1.20 |
$ 0.74 |
The Company believes that providing a measure of F&D costs is useful for investors as a means of evaluating a Company's cost to add proved reserves on a per thousand cubic feet of natural gas equivalent basis. These measures are provided in addition to, and not as an alternative for the financial statements, including the notes thereto, contained in Southwestern's Annual Report. Due to various factors, including timing differences, F&D costs do not necessarily reflect precisely the costs associated with particular reserves. For example, exploration costs may be recorded in periods prior to the periods in which related acquisitions and increases in reserves are recorded and development costs, including future development costs for proved undeveloped reserve additions, may be recorded in periods subsequent to the periods in which related increases in reserves are recorded. In addition, changes in commodity prices can affect the magnitude of recorded increases in reserves independent of the related costs of such increases. As a result of the foregoing factors and various factors that could materially affect the timing and amounts of future increases in reserves and the timing and amounts of future costs, including factors disclosed in Southwestern's filings with the SEC, future F&D costs may differ materially from those set forth above. Further, the methods used by Southwestern to calculate its F&D costs may differ significantly from methods used by other companies to compute similar measures and, as a result, Southwestern's F&D costs may not be comparable to similar measures provided by other companies.
Southwestern management will host a teleconference call on Friday, February 26, 2016 at 10:00 a.m. EST to discuss its fourth quarter and year-end 2015 results. The toll-free number to call is 877-407-8035 and the international dial-in number is 201-689-8035. The teleconference can also be heard "live" on the Internet at http://www.swn.com.
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the Company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
OPERATING STATISTICS (Unaudited) |
Page 1 of 5 | |||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the year ended | |||||||||||
December 31, |
December 31, | |||||||||||
2015 |
2014 |
2015 |
2014 | |||||||||
Exploration & Production |
||||||||||||
Production |
||||||||||||
Gas production (Bcf) |
226 |
199 |
899 |
766 | ||||||||
Oil production (MBbls) |
569 |
121 |
2,265 |
235 | ||||||||
NGL production (MBbls) |
3,328 |
204 |
10,702 |
231 | ||||||||
Total production (Bcfe) |
249 |
201 |
976 |
768 | ||||||||
Commodity Prices |
||||||||||||
Average realized gas price per Mcf, including hedges |
$ |
2.07 |
$ |
3.52 |
$ |
2.37 |
$ |
3.72 | ||||
Average realized gas price per Mcf, excluding hedges |
$ |
1.48 |
$ |
3.26 |
$ |
1.91 |
$ |
3.74 | ||||
Average oil price per Bbl |
$ |
27.36 |
$ |
60.51 |
$ |
33.25 |
$ |
79.91 | ||||
Average NGL price per Bbl |
$ |
7.62 |
$ |
12.38 |
$ |
6.80 |
$ |
15.72 | ||||
Summary of Derivative Activity in the Statement of Operations |
||||||||||||
Settled commodity amounts included in "Operating Revenues" (in millions) |
$ |
64 |
$ |
22 |
$ |
209 |
$ |
(26) | ||||
Settled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
69 |
$ |
31 |
$ |
206 |
$ |
10 | ||||
Unsettled commodity amounts included in "Gain (Loss) on Derivatives" (in millions) |
$ |
(50) |
$ |
140 |
$ |
(153) |
$ |
137 | ||||
Average unit costs per Mcfe |
||||||||||||
Lease operating expenses |
$ |
0.91 |
$ |
0.90 |
$ |
0.92 |
$ |
0.91 | ||||
General & administrative expenses |
$ |
0.20 |
$ |
0.24 |
$ |
0.21 |
$ |
0.24 | ||||
Taxes, other than income taxes |
$ |
0.09 |
$ |
0.10 |
$ |
0.10 |
$ |
0.11 | ||||
Full cost pool amortization |
$ |
0.78 |
$ |
1.12 |
$ |
1.00 |
$ |
1.10 | ||||
Midstream |
||||||||||||
Volumes marketed (Bcfe) |
290 |
234 |
1,127 |
904 | ||||||||
Volumes gathered (Bcf) |
179 |
243 |
799 |
963 |
STATEMENTS OF OPERATIONS (Unaudited) |
Page 2 of 5 | |||||||||||
Southwestern Energy Company and Subsidiaries |
||||||||||||
For the three months ended |
For the years ended | |||||||||||
December 31, |
December 31, | |||||||||||
2015 |
2014 |
2015 |
2014 | |||||||||
(in millions, except share/per share amounts) | ||||||||||||
Operating Revenues |
||||||||||||
Gas sales |
$ |
406 |
$ |
672 |
$ |
1,946 |
$ |
2,827 | ||||
Oil sales |
16 |
7 |
76 |
19 | ||||||||
NGL sales |
26 |
2 |
73 |
3 | ||||||||
Marketing |
200 |
231 |
863 |
996 | ||||||||
Gas gathering |
39 |
50 |
175 |
193 | ||||||||
687 |
962 |
3,133 |
4,038 | |||||||||
Operating Costs and Expenses |
||||||||||||
Marketing purchases |
198 |
228 |
852 |
980 | ||||||||
Operating expenses |
182 |
118 |
689 |
427 | ||||||||
General and administrative expenses |
58 |
59 |
246 |
221 | ||||||||
Depreciation, depletion and amortization |
215 |
249 |
1,091 |
942 | ||||||||
Impairment of natural gas and oil properties |
2,576 |
– |
6,950 |
– | ||||||||
Gain on sale of assets, net |
(7) |
– |
(283) |
– | ||||||||
Taxes, other than income taxes |
26 |
23 |
110 |
95 | ||||||||
3,248 |
677 |
9,655 |
2,665 | |||||||||
Operating Income (Loss) |
(2,561) |
285 |
(6,522) |
1,373 | ||||||||
Interest Expense |
||||||||||||
Interest on debt |
47 |
26 |
200 |
101 | ||||||||
Other interest charges |
6 |
9 |
60 |
13 | ||||||||
Interest capitalized |
(49) |
(15) |
(204) |
(55) | ||||||||
4 |
20 |
56 |
59 | |||||||||
Other Loss, Net |
(32) |
(5) |
(30) |
(4) | ||||||||
Gain on Derivatives |
17 |
168 |
47 |
139 | ||||||||
Income (Loss) Before Income Taxes |
(2,580) |
428 |
(6,561) |
1,449 | ||||||||
Provision (Benefit) for Income Taxes |
||||||||||||
Current |
(9) |
(13) |
(2) |
21 | ||||||||
Deferred |
(464) |
129 |
(2,003) |
504 | ||||||||
(473) |
116 |
(2,005) |
525 | |||||||||
Net Income (Loss) |
$ |
(2,107) |
$ |
312 |
$ |
(4,556) |
$ |
924 | ||||
Mandatory convertible preferred stock dividend |
27 |
– |
106 |
– | ||||||||
Net Income (Loss) Attributable to Common Stock |
(2,134) |
312 |
(4,662) |
924 | ||||||||
Earnings (Loss) Per Common Share |
||||||||||||
Basic |
$ |
(5.58) |
$ |
0.89 |
$ |
(12.25) |
$ |
2.63 | ||||
Diluted |
$ |
(5.58) |
$ |
0.88 |
$ |
(12.25) |
$ |
2.62 | ||||
Weighted Average Common Shares Outstanding | ||||||||||||
Basic |
382,334,978 |
351,710,349 |
380,521,039 |
351,446,747 | ||||||||
Diluted |
382,334,978 |
352,289,601 |
380,521,039 |
352,410,683 |
BALANCE SHEETS (Unaudited) |
Page 3 of 5 | |||||
Southwestern Energy Company and Subsidiaries |
||||||
December 31, |
December 31, | |||||
2015 |
2014 | |||||
(in millions) | ||||||
ASSETS |
||||||
Current assets |
$ |
393 |
$ |
1,115 | ||
Property and equipment |
24,364 |
22,557 | ||||
Less: Accumulated depreciation, depletion and amortization |
(16,821) |
(8,845) | ||||
Total property and equipment, net |
7,543 |
13,712 | ||||
Other long-term assets |
174 |
98 | ||||
Total assets |
8,110 |
14,925 | ||||
LIABILITIES AND EQUITY |
||||||
Current liabilities |
707 |
5,428 | ||||
Long-term debt |
4,728 |
2,466 | ||||
Deferred income taxes |
– |
1,951 | ||||
Other long-term liabilities |
393 |
418 | ||||
Total liabilities |
5,828 |
10,263 | ||||
Equity: |
||||||
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 390,138,549 shares in 2015 and 354,488,992 shares in 2014 |
4 |
4 | ||||
Preferred stock, $0.01 par value; 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding as of December 31, 2015 |
– |
– | ||||
Additional paid-in capital |
3,409 |
1,019 | ||||
Retained earnings (Accumulated deficit) |
(1,082) |
3,577 | ||||
Accumulated other comprehensive income (loss) |
(48) |
62 | ||||
Common stock in treasury; 47,149 shares in 2015 and 11,055 shares in 2014 |
(1) |
– | ||||
Total equity |
2,282 |
4,662 | ||||
Total liabilities and equity |
$ |
8,110 |
$ |
14,925 |
STATEMENTS OF CASH FLOWS (Unaudited) |
Page 4 of 5 | |||||
Southwestern Energy Company and Subsidiaries |
||||||
For the years ended December 31, | ||||||
2015 |
2014 | |||||
(in millions) | ||||||
Cash Flows From Operating Activities |
||||||
Net income (loss) |
$ |
(4,556) |
$ |
924 | ||
Adjustment to reconcile net income to net cash provided by operating activities: |
||||||
Depreciation, depletion and amortization |
1,092 |
942 | ||||
Impairment of natural gas and oil properties |
6,950 |
– | ||||
Amortization of debt issuance cost |
53 |
10 | ||||
Deferred income taxes |
(2,003) |
504 | ||||
(Gain) loss on derivatives, net of settlement |
155 |
(130) | ||||
Stock-based compensation |
26 |
18 | ||||
Gain on sale of assets, net |
(283) |
– | ||||
Write-down of inventory |
32 |
– | ||||
Other |
2 |
2 | ||||
Change in assets and liabilities |
112 |
65 | ||||
Net cash provided by operating activities |
1,580 |
2,335 | ||||
Cash Flows From Investing Activities |
||||||
Capital investments |
(1,798) |
(2,043) | ||||
Acquisitions |
(579) |
(5,298) | ||||
Proceeds from sale of property and equipment |
729 |
43 | ||||
Other |
10 |
10 | ||||
Net cash used in investing activities |
(1,638) |
(7,288) | ||||
Cash Flows From Financing Activities |
||||||
Payments on current portion of long-term debt |
(1) |
(1) | ||||
Payments on long-term debt |
(500) |
– | ||||
Payments on short-term debt |
(4,500) |
– | ||||
Payments on revolving credit facility |
(3,024) |
(5,179) | ||||
Borrowings under revolving credit facility |
2,840 |
5,196 | ||||
Payments on commercial paper |
(7,988) |
– | ||||
Borrowings under commercial paper |
7,988 |
– | ||||
Change in bank drafts outstanding |
12 |
11 | ||||
Proceeds from issuance of long-term debt |
2,950 |
500 | ||||
Proceeds from issuance of short-term debt |
– |
4,500 | ||||
Debt issuance costs |
(20) |
(56) | ||||
Proceeds from exercise of common stock options |
– |
12 | ||||
Proceeds from issuance of common stock |
669 |
– | ||||
Proceeds from issuance of mandatory convertible preferred stock |
1,673 |
– | ||||
Mandatory convertible preferred stock dividend |
(79) |
– | ||||
Net cash provided by financing activities |
20 |
4,983 | ||||
Increase (decrease) in cash and cash equivalents |
(38) |
30 | ||||
Cash and cash equivalents at beginning of year |
53 |
23 | ||||
Cash and cash equivalents at end of year |
$ |
15 |
$ |
53 |
SEGMENT INFORMATION (Unaudited) |
Page 5 of 5 |
||||||||||||||||
Southwestern Energy Company and Subsidiaries |
|||||||||||||||||
Exploration |
|||||||||||||||||
& |
Midstream |
||||||||||||||||
Production |
Services |
Other |
Eliminations |
Total | |||||||||||||
(in millions) |
|||||||||||||||||
Quarter Ending December 31, 2015 |
|||||||||||||||||
Revenues |
$ |
441 |
$ |
668 |
$ |
(1) |
$ |
(421) |
$ |
687 | |||||||
Marketing purchases |
– |
541 |
– |
(343) |
198 | ||||||||||||
Operating expenses |
229 |
33 |
(2) |
(78) |
182 | ||||||||||||
General & administrative expenses |
49 |
9 |
– |
– |
58 | ||||||||||||
Depreciation, depletion & amortization |
204 |
10 |
1 |
– |
215 | ||||||||||||
Impairment of natural gas properties |
2,576 |
– |
– |
– |
2,576 | ||||||||||||
Gain on sale of assets, net |
(7) |
– |
– |
– |
(7) | ||||||||||||
Taxes, other than income taxes |
23 |
3 |
– |
– |
26 | ||||||||||||
Operating income (loss) |
(2,633) |
72 |
– |
– |
(2,561) | ||||||||||||
Capital investments(1) |
378 |
3 |
2 |
– |
383 | ||||||||||||
Quarter Ending December 31, 2014 |
|||||||||||||||||
Revenues |
$ |
680 |
$ |
1,014 |
$ |
– |
$ |
(732) |
$ |
962 | |||||||
Marketing purchases |
– |
855 |
– |
(627) |
228 | ||||||||||||
Operating expenses |
180 |
42 |
1 |
(105) |
118 | ||||||||||||
General & administrative expenses |
49 |
10 |
– |
– |
59 | ||||||||||||
Depreciation, depletion & amortization |
234 |
15 |
– |
– |
249 | ||||||||||||
Taxes, other than income taxes |
21 |
3 |
(1) |
– |
23 | ||||||||||||
Operating income |
196 |
89 |
– |
– |
285 | ||||||||||||
Capital investments(1) |
5,548 |
35 |
27 |
– |
5,610 | ||||||||||||
Year Ending December 31, 2015 |
|||||||||||||||||
Revenues |
$ |
2,074 |
$ |
3,119 |
$ |
– |
$ |
(2,060) |
$ |
3,133 | |||||||
Marketing purchases |
– |
2,566 |
– |
(1,714) |
852 | ||||||||||||
Operating expenses |
899 |
136 |
– |
(346) |
689 | ||||||||||||
General & administrative expenses |
207 |
39 |
– |
– |
246 | ||||||||||||
Depreciation, depletion & amortization |
1,028 |
62 |
1 |
– |
1,091 | ||||||||||||
Impairment of natural gas properties |
6,950 |
– |
– |
– |
6,950 | ||||||||||||
Gain on sale of assets, net |
(6) |
(277) |
– |
– |
(283) | ||||||||||||
Taxes, other than income taxes |
100 |
10 |
– |
– |
110 | ||||||||||||
Operating income (loss) |
(7,104) |
583 |
(1) |
– |
(6,522) | ||||||||||||
Capital investments(1) |
2,258 |
167 |
12 |
– |
2,437 | ||||||||||||
Year Ending December 31, 2014 |
|||||||||||||||||
Revenues |
$ |
2,862 |
$ |
4,358 |
$ |
– |
$ |
(3,182) |
$ |
4,038 | |||||||
Marketing purchases |
– |
3,738 |
– |
(2,758) |
980 | ||||||||||||
Operating expenses |
697 |
153 |
1 |
(424) |
427 | ||||||||||||
General & administrative expenses |
183 |
38 |
– |
– |
221 | ||||||||||||
Depreciation, depletion & amortization |
884 |
58 |
– |
– |
942 | ||||||||||||
Taxes, other than income taxes |
85 |
10 |
– |
– |
95 | ||||||||||||
Operating income (loss) |
1,013 |
361 |
(1) |
– |
1,373 | ||||||||||||
Capital investments(1) |
7,254 |
144 |
49 |
– |
7,447 | ||||||||||||
(1) Capital investments includes a decrease of $28 million and an increase of $41 million for the three months ended December 31, 2015 and 2014, respectively, and a decrease of $33 million and an increase of $155 million for the years ended December 31, 2015 and 2014, respectively, relating to the change in accrued expenditures between periods. |
|||||||||||||||||
Photo - http://photos.prnewswire.com/prnh/20160225/337603
SOURCE Southwestern Energy Company
HOUSTON, Feb. 25, 2016 /PRNewswire/ -- Southwestern Energy Company (NYSE: SWN) today provided an update on its strategic plans for 2016 and the initiatives it is taking to position the Company for long-term value creation.
"We will capitalize on our premier quality assets, significant hydrocarbon resource and strong liquidity position to proactively address the challenges presented by the current commodity price environment. Our strategic plan will enable us to optimize the business in today's constrained environment while positioning us to outperform when commodity prices improve," stated Bill Way, President and Chief Executive Officer of Southwestern Energy. "Looking ahead, we are dedicated to operational excellence and remaining flexible as we continue to pursue our objective of keeping our investing levels within cash flow.
We have taken clear and decisive actions to create long-term value for our shareholders, including reducing activity to align with current commodity prices. We have a clear focus on identifying opportunities to further strengthen our balance sheet, enhancing operating margins through both revenue and cost improvements and optimizing cash flow throughout the Company. We will maintain our capital discipline by only investing in projects that exceed our 1.3 PVI threshold at strip prices. We are confident that this plan will strengthen the Company, putting us on a path to return to value-adding growth for our shareholders."
2016 Strategy
Throughout 2016, the Company will focus on further strengthening its balance sheet, enhancing margins and optimizing its portfolio of premier quality assets. Details on these initiatives are described below.
Commenting on the initiatives, Bill Way stated, "As we navigate this challenging time for our industry, the combination of our premier assets and the prudent strategic plan being implemented in 2016 provides the setting for a future that holds significant value for our shareholders."
2016 Guidance
With the Company's focus on balance sheet strength and capital discipline, activity levels in 2016 will be driven by the commodity price environment. As commodity prices and cash flows fluctuate, the Company expects to adjust its capital investment accordingly.
The following table provides detailed information for 2016 based on an average natural gas price of $2.35 per Mcf and an average oil price of $35.00 per barrel. At these levels, capital activity will primarily be targeted at managing the Company's existing drilled but uncompleted well inventory. As a reminder, the Company is not currently running any rigs throughout its portfolio.
Gas/Oil Prices | |||
2015 |
2016 | ||
$MM's (except production and well count) |
$2.66 / $48.80 |
$2.35 / $35.00 | |
Capital: |
|||
Discretionary Capital |
$1,438 |
$100 - $125 | |
Capitalized Interest and Expenses |
$ 390 |
$250 - $275 | |
Total Capital (1) |
$1,828 |
$350 - $400 | |
Net Cash Provided by Operating Activities before changes in operating assets and liabilities (2) (3) |
$1,468 |
$450 - $500 | |
Adjusted net income (loss) attributable to common stock (2) (3) |
$71 |
$(160) - $(180) | |
Adjusted EBITDA (2) (3) |
$1,440 |
$450 - $500 | |
Production (Bcfe) |
976 |
815 - 835 | |
Wells Drilled |
380 |
- | |
Wells to Sales |
410 |
20 - 30 | |
Ending Drilled But Uncompleted Well Inventory |
128 |
100 -110 | |
(1) Excludes the $609 million of acquisition costs and post-closing adjustments for the Appalachia transactions that closed in December 2014 and January 2015 | |||
(2) Excludes the impact of one-time severance charges associated with the 1Q 2016 workforce reduction | |||
(3) This represents a Non-GAAP measure; see "Explanation and Reconciliation of Non-GAAP Financial Measures" below |
The Company's plan is flexible and designed to be responsive to any commodity price strengthening. A natural gas price increase of $0.25 per Mcf or an oil price increase of $5.00 per barrel would increase cash flow by approximately $185 million and $15 million, respectively. Assuming this added cash flow is invested into additional completion activities, this would result in increased production of approximately 70 Bcfe for the first twelve months. Cash flow beyond this level could be allocated to drilling opportunities. The impacts of running one rig is shown below for each of the Company's operating areas:
Impact of 1 Additional Rig: | |||||
NE Appalachia |
SW Appalachia |
Fayetteville | |||
Capital |
$ 185 |
$ 100 |
$ 140 | ||
Year 1 Production (Bcfe) |
18 |
11 |
10 | ||
Year 2 Production (Bcfe) |
52 |
35 |
12 |
Assuming average natural gas and oil prices of $2.35 and $35.00, respectively, Southwestern is expecting total net production of 815 to 835 Bcfe in 2016. In Northeast Appalachia, the Company expects total net production in 2016 to be 324 to 332 Bcf. Total net production from Southwest Appalachia is expected to be 125 to 130 Bcfe, of which approximately half is estimated to be liquids. Total net production from the Fayetteville Shale in 2016 is expected to be 364 to 371 Bcf. Additional details of expected results are noted below:
Estimated Production by Quarter in 2016
1st Quarter |
2nd Quarter |
3rd Quarter |
4th Quarter |
Full-Year | |
Total Production (Bcfe) |
230 – 235 |
210 – 215 |
195 – 200 |
180 – 185 |
815 – 835 |
Natural Gas (Bcf) |
209 – 213 |
193 – 197 |
180 – 185 |
167 – 171 |
749 – 766 |
Oil (MBbls) |
570 – 600 |
470 – 500 |
405 – 435 |
355 – 385 |
1,800 – 1,920 |
NGLs (MBbls) |
3,000 – 3,075 |
2,300 – 2,375 |
2,050 – 2,125 |
1,875 – 1,950 |
9,225 – 9,525 |
Estimated E&P Pricing Deductions in 2016 |
|
Avg Gas Basis Differential and Transportation Charge |
$0.73 - $0.83 per Mcf |
Avg Oil Basis Differential and Transportation Charge |
$13.00 - $15.00 per Bbl |
Estimated E&P Operating Expenses in 2016 (per Mcfe) |
|
Lease Operating Expenses |
$0.90 - $0.95 |
General & Administrative Expense |
$0.22 - $0.26 |
Taxes, Other Than Income Taxes |
$0.09 - $0.11 |
Other Items in 2016 |
|
Midstream EBITDA ($ in millions) |
$235 - $250 |
Net Interest Expense ($ in millions) |
$53 - $58 |
Income Tax Rate (~100% Deferred) |
38.0% |
The Company currently has hedges in place for 37 Bcf of 2016 gas production at an average price of $2.60 per Mcf. The Company continues to assess the potential for additional hedges to be added to the portfolio to de-risk the potential for further price deterioration without materially limiting the benefits of an improved price environment.
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 and 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. Adjusted net cash provided by operating activities before changes in operating assets and liabilities also excludes the impact of one-time cash severance payments associated with the first quarter of 2016 workforce reduction.
Additional non-GAAP financial measures referenced in this news release are adjusted net income and adjusted EBITDA. Management presents these measures because (i) they are consistent with the manner in which the Company's performance is measured relative to the performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the Company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
See the reconciliations below of GAAP financial measures to non-GAAP financial measures for the 2015 and forecasted 2016 annual periods. Non-GAAP financial measures should not be considered in isolation or as a substitute for the Company's reported results prepared in accordance with GAAP.
2015 Actual |
2016 Guidance | |
NYMEX Price |
NYMEX Price Assumption | |
($ millions) |
$2.66 Gas / $48.80 Oil |
$2.35 Gas / $35.00 Oil |
Cash flow from operating activities: |
||
Net cash provided by operating activities |
$1,580 |
$405 - $450 |
Add back (deduct): |
||
One-time cash severance payments |
- |
45 - 50 |
Change in operating assets and liabilities |
(112) |
- |
Net cash flow |
$1,468 |
$450 - $500 |
2015 Actual |
2016 Guidance | |
NYMEX Price |
NYMEX Price | |
($ millions) |
$2.66 Gas / $48.80 Oil |
$2.35 Gas / $35.00 Oil |
Net loss attributable to common stock |
$(4,662) |
$(197) - $(223) |
Add back (deduct): |
||
Participating securities – mandatory convertible preferred stock |
(13) |
- |
Impairment of natural gas and oil properties (net of taxes) |
4,287 |
- |
Gain on sale of assets (net of taxes) |
(174) |
- |
Loss on certain derivatives (net of taxes) |
96 |
- |
Adjustments due to discrete tax items |
483 |
- |
Adjustments due to inventory valuation (net of taxes) |
20 |
- |
Transaction costs (net of taxes) |
33 |
- |
Restructuring costs (net of taxes) |
1 |
37 - 43 |
Adjusted net income (loss) attributable to common stock |
$71 |
$(160) - $(180) |
2015 Actual |
2016 Guidance | |
NYMEX Price |
NYMEX Price Assumption | |
$2.66 Gas / $48.80 Oil |
$2.35 Gas / $35.00 Oil | |
($ in millions) | ||
Net loss attributable to common stock |
$(4,662) |
$(197) - $(223) |
Add back: |
||
Mandatory convertible preferred stock dividend |
106 |
108 - 108 |
Net loss attributable to SWN |
$(4,556) |
$(89) - $(115) |
Add back: |
||
Provision for income taxes |
(2,005) |
(54) - (70) |
Impairment of natural gas and oil properties |
6,950 |
- |
Gain on sale of assets |
(283) |
- |
Loss on derivatives excluding derivatives, settled |
155 |
- |
Interest expense |
56 |
53 - 58 |
Write-down on inventory |
32 |
- |
Restructuring costs |
- |
60 - 70 |
Depreciation, depletion and amortization |
1,091 |
520 - 530 |
Adjusted EBITDA |
$1,440 |
$450 - $500 |
Southwestern Energy Company is an independent energy company whose wholly-owned subsidiaries are engaged in natural gas and oil exploration, development and production, natural gas gathering and marketing. Additional information on the company can be found on the Internet at http://www.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; changes in expected levels of natural gas and oil reserves or production; operating hazards, drilling risks, unsuccessful exploratory activities; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; international monetary conditions; unexpected cost increases; potential liability for remedial actions under existing or future environmental regulations; potential liability resulting from pending or future litigation; and general domestic and international economic and political conditions; as well as changes in tax, environmental and other laws 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.
SOURCE Southwestern Energy Company
HOUSTON, Feb. 15, 2016 /PRNewswire/ -- In conjunction with Southwestern Energy Company's 2015 Fourth Quarter earnings release, you are invited to listen to its conference call that will be broadcast live over the Internet on Friday, February 26, 2016, at 10:00 a.m. EST with Bill Way, President and Chief Executive Officer of Southwestern Energy Company. Southwestern Energy Company announces the following Webcast:
What: |
Southwestern Energy Company's Fourth Quarter 2015 Earnings |
When: |
February 26, 2016 @ 10:00 a.m. EST |
Where: |
|
How: |
Live over the Internet -- Simply log on to the web at the address above or go to the Company's Web site: www.swn.com |
If you are unable to participate during the live webcast, the call will be archived on the Company's Web site: www.swn.com. To access the replay, look under "Latest News."
Southwestern Energy Company (NYSE: SWN) is an integrated natural gas company whose wholly-owned subsidiaries are engaged in oil and natural gas exploration and production, natural gas gathering and marketing. Additional information on the Company can be found on the internet at http://www.swn.com.
SOURCE Southwestern Energy Company
Southwestern Appalachia Water Infrastructure (subscriber access)
Status: (subscriber access)
Parent Entities:
Southwestern Energy Co.
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