WPX Energy’s (WPX) unaudited results for the third quarter of 2014 reflect the benefit of continued increases in crude oil production and greater balance in commodity revenue streams, as well as the reclassification of coalbed methane properties in the Powder River Basin to discontinued operations.
Domestic oil production climbed 52 percent higher in third-quarter 2014 vs. third-quarter 2013. WPX’s crude oil production in the Williston Basin surpassed an average of 20,000 barrels per day during third-quarter 2014. In the San Juan Basin, WPX sold its one millionth net barrel of oil from the Gallup play in less than 18 months after initial production while averaging 1.5 rigs during this time.
During the third quarter, oil and liquids (NGL) sales accounted for 56 percent of WPX’s domestic product revenues of $453 million and nearly 26 percent of the company’s domestic production volumes of just over 1 billion cubic feet per day equivalent.
WPX is in the process of completing the sale of its mature coalbed methane properties in the Powder River Basin. WPX signed an agreement in August and expects to complete the transaction in December. Results from these properties are now reflected as discontinued operations for all periods.
“A more focused and more balanced WPX is emerging,” said Rick Muncrief, WPX president and chief executive officer. “We’re simplifying our story, leveraging the optionality in our portfolio and pursuing a long-term margin expansion strategy.”
POST-QUARTER ITEMS
On Oct. 3, WPX announced an agreement to sell its international interests for approximately $294 million subject to the successful completion of the definitive merger agreement entered into between privately held Pluspetrol Resources Corporation and Apco Oil and Gas International. WPX has a 69 percent controlling equity interest in Apco.
Additionally, WPX’s gas sales agreement with a firm shipper on the Rockies Express Pipeline expires on Nov. 11, 2014, and is expected to improve natural gas revenues by more than $100 million on an annualized basis.
Both of these items will be reflected in WPX’s fourth-quarter results since they are occurring subsequent to the close of the third-quarter.
THIRD-QUARTER AND NINE-MONTH 2014 FINANCIAL RESULTS
WPX reported unaudited net income attributable to WPX Energy of $62 million for third-quarter 2014, or income of $0.30 per share on a diluted basis, compared with a net loss of $114 million, or a loss of $0.57 per share, in the same period a year ago.
Income from continuing operations attributable to WPX Energy was $57 million for third-quarter 2014, or income of $0.28 per share on a diluted basis compared with a net loss from continuing operations of $106 million, or a loss of $0.53 per share, in the same period a year ago.
Results for third-quarter 2014 benefitted from a 29 percent increase in domestic oil revenue vs. a year ago, which was offset by a 2 percent decrease in domestic natural gas revenue, the impact of approximately $22 million in impairments of domestic exploratory leasehold and well costs, and nearly $14 million in expenses related to an early exit program and the release of a rig to a third party.
For the first nine months of 2014, WPX reported an unaudited net loss attributable to WPX Energy of $55 million, or a loss of $0.27 per share on a diluted basis, compared with a net loss of $212 million, or a loss of $1.06 per share, for the same period in 2013.
Loss from continuing operations attributable to WPX Energy for the first nine months of the year was $85 million, or a loss of $0.42 per share, compared with a loss of $202 million, or a loss of $1.01 per share, for the same period in 2013.
Results for the first nine months of 2014 were impacted by a $196 million before-tax loss associated with the sale of a portion of WPX’s working interests in certain Piceance Basin natural gas wells, $62 million in dry-hole cost and impairments of domestic exploratory leasehold and well costs, and $16 million in expenses related to an early exit program and the release of a rig to a third party. The first nine months of 2013 included a $19 million impairment to the company’s cost of acquired unproved reserves.
Excluding unrealized mark-to-market gains (losses), impairments of exploratory leasehold and well costs, early exit program expenses, and an early rig release expense, WPX had an adjusted loss from continuing operations of $4 million, or a loss of $0.02 per share on a diluted basis, for third-quarter 2014, compared with an adjusted loss from continuing operations of $80 million, or a loss of $0.39 per share, for the same period in 2013. A reconciliation accompanies this press release.
For the first nine months of 2014, WPX had adjusted income from continuing operations of $30 million, or income of $0.14 per share on a diluted basis, compared with an adjusted loss of $173 million, or a loss of $0.86 per share, for the first nine months of 2013. A reconciliation accompanies this press release.
Improved results for the first nine months of 2014 reflect the benefit of a 40 percent increase in domestic oil revenues, along with higher weighted average gross sales prices for domestic natural gas and natural gas liquids.
The weighted average gross sales price – prior to revenue deductions – for domestic natural gas was $3.30 per Mcf in third-quarter 2014 compared with $3.15 per Mcf a year ago.
The weighted average gross sales price – prior to revenue deductions – for domestic oil was $84.76 per barrel in third-quarter 2014 compared with $99.52 per barrel a year ago.
The weighted average gross sales price – prior to revenue deductions – for domestic NGL was $43.42 per barrel in third-quarter 2014 compared with $43.11 per barrel a year ago.
ADJUSTED EBITDAX
WPX’s adjusted EBITDAX (a non-GAAP measure) for third-quarter 2014 was $230 million, an increase of 32 percent compared with $174 million for the same period in 2013.
For the first nine months of 2014, WPX’s adjusted EBITDAX was $797 million, up 41 percent compared with $564 million for the same period in 2013.
The primary factors contributing to the increase in 2014 adjusted EBITDAX are increased domestic oil volumes and the corresponding increase in domestic oil revenues, as well as higher net realized average prices for natural gas.
| EBITDAX (non-GAAP) | Third Quarter | YTD | |||||||||||||||||||
| 2014 | 2013 | 2014 | 2013 | ||||||||||||||||||
|
millions |
millions |
millions |
millions |
||||||||||||||||||
| Net income (loss) | $ | 66 | ($116 | ) | ($48 | ) | ($207 | ) | |||||||||||||
| Interest expense | $ | 31 | $ | 28 | $ | 88 | $ | 82 | |||||||||||||
| Provision (benefit) for income taxes | $ | 28 | ($29 | ) | ($31 | ) | ($79 | ) | |||||||||||||
| Depreciation, depletion and amortization | $ | 213 | $ | 230 | $ | 627 | $ | 662 | |||||||||||||
| Exploration expenses | $ | 29 | $ | 21 | $ | 101 | $ | 59 | |||||||||||||
| EBITDAX | $ | 367 | $ | 134 | $ | 737 | $ | 517 | |||||||||||||
| Impairment of producing properties, costs of acquired unproved reserves and | |||||||||||||||||||||
| equity investments | – | $ | 19 | – | $ | 19 | |||||||||||||||
| Loss on sale of working interests in the Piceance Basin | $ | 1 | – | $ | 196 | – | |||||||||||||||
| Net (gain) loss on derivatives not designated as hedges | ($148 | ) | $ | 15 | $ | 64 | $ | 31 | |||||||||||||
| Net cash received (paid) on settlement of derivatives not designated as hedges | $ | 15 | ($2 | ) | ($170 | ) | ($13 | ) | |||||||||||||
| (Income) loss from discontinued operations | ($5 | ) | $ | 8 | ($30 | ) | $ | 10 | |||||||||||||
| ADJUSTED EBITDAX | $ | 230 | $ | 174 | $ | 797 | $ | 564 | |||||||||||||
EBITDAX represents earnings before interest expense, income taxes, depreciation, depletion and amortization and exploration expenses. Adjusted EBITDAX includes adjustments for net (gain) loss on derivatives not designated as hedges, loss on the sale of working interests in the Piceance Basin, net cash received (paid) on settlement of derivatives not designated as hedges, impairments and discontinued operations.
WPX believes these non-GAAP measures provide useful information regarding its ability to meet future debt service, capital expenditures and working capital requirements.
CEO PERSPECTIVE
“We have a clear vision for creating value,” said Rick Muncrief, referring to WPX’s five-year plan that aims to increase oil production five-fold and triple its margins and company value by the year 2020.
“Already this year, we’ve entered into a series of transactions to reposition WPX that represent an aggregate value of more than $1 billion. We’re going to remain aggressive, creative and opportunistic as we execute our plan.
“It’s also important for us to stay focused on the long-term as we see volatility in the markets. For 2015, we’ve locked in about half of our projected oil volumes at an average of nearly $95 per barrel and about half of our expected natural gas production at just over $4.25 per MMbtu.
“We’re directly linking our hedging to our capital plan, which gives us confidence in the cash flow that supports our drilling program,” Muncrief added.
PRODUCTION
WPX’s overall domestic and international production for third-quarter 2014 – not including volumes for discontinued operations – was 1,065 MMcfe/d, consistent with the company’s guidance for volumes of 1,060 to 1,073 MMcfe/d.
Production figures for 2014, specifically natural gas and NGL, reflect the absence of volumes due to the sale of working interests in certain of WPX’s Piceance Basin wells earlier this year.
After adjusting the volumes in previous quarters for the impact of the sale of working interests in the Piceance wells, overall third-quarter 2014 equivalent volumes would have increased 5 percent vs. a year ago and 2 percent vs. the sequential quarter.
| Average Daily Production | 3Q | 2Q | Sequential | |||||||||||||
| 2014 | 2013 | Change | 2014 | Change | ||||||||||||
| Natural gas (MMcf/d) | ||||||||||||||||
| Piceance Basin | 542 | 603 | -10 | % | 584 | -7 | % | |||||||||
| Appalachian Basin | 79 | 91 | -13 | % | 88 | -10 | % | |||||||||
| San Juan Basin | 111 | 117 | -5 | % | 107 | 4 | % | |||||||||
| International | 21 | 19 | 11 | % | 20 | 5 | % | |||||||||
| Other | 13 | 9 | 44 | % | 12 | 8 | % | |||||||||
| Subtotal (MMcf/d) | 766 | 839 | -9 | % | 811 | -6 | % | |||||||||
| Oil (Mbbl/d) | ||||||||||||||||
| Williston Basin | 20.1 | 14.0 | 44 | % | 18.8 | 7 | % | |||||||||
| San Juan Basin | 3.9 | 1.1 | 255 | % | 3.0 | 30 | % | |||||||||
| Piceance Basin | 1.7 | 1.7 | 0 | % | 2.0 | -15 | % | |||||||||
| International | 6.5 | 5.3 | 23 | % | 5.2 | 25 | % | |||||||||
| Other | 0.1 | 0.2 | -50 | % | 0.0 | NM | ||||||||||
| Subtotal (Mbbl/d) | 32.3 | 22.3 | 45 | % | 29.0 | 11 | % | |||||||||
| NGLs (Mbbl/d) | ||||||||||||||||
| Piceance | 14.5 | 18.4 | -21 | % | 15.8 | -8 | % | |||||||||
| International | 0.4 | 0.5 | -20 | % | 0.4 | 0 | % | |||||||||
| Other | 2.6 | 1.2 | 117 | % | 2.1 | 24 | % | |||||||||
| Subtotal (Mbbl/d) | 17.5 | 20.1 | -13 | % | 18.3 | -4 | % | |||||||||
| Total Production (MMcfe/d) | 1,065 | 1,094 | -3 | % | 1,095 | -3 | % | |||||||||
| NM is a percentage calculation that is not meaningful. | ||||||||||||||||
Consolidated natural gas production of 766 MMcf/d in third-quarter 2014 was within the range of the company’s guidance of 763 to 773 MMcf/d. Piceance Basin volumes of 542 MMcf/d accounted for 73 percent of WPX’s third-quarter domestic natural gas production. Piceance volumes were hampered by third-party gathering outages during the third quarter.
WPX’s domestic oil production continues to climb rapidly, increasing 52 percent year-over-year. Domestic oil production was driven by higher volumes in the San Juan Basin’s Gallup Play, which grew 255 percent year-over-year and 30 percent vs. the sequential quarter. Oil production also showed sizable growth in the Williston Basin, up 44 percent year-over-year.
Consolidated natural gas liquids (NGL) production of 17.5 Mbbl/d was in line with WPX’s third-quarter guidance range of 17.4 to 17.8 Mbbl/d, but lower than a year ago and sequential quarter due in part to an ethane recovery rate of 20 percent during third-quarter 2014.
Notably, oil and liquids (NGL) production accounted for nearly 26 percent of WPX’s total domestic production, up from 21 percent in third-quarter 2013. Oil volumes alone accounted for 15 percent of WPX’s overall third-quarter domestic production.
EXPENSES
WPX’s domestic operating expenses were approximately 3 percent lower in third-quarter 2014 than the same period in 2013.
WPX’s domestic lease and facility operating expenses for third-quarter 2014 were $63 million vs. $62 million in the same period in 2013.
Domestic gathering, processing and transportation charges of $82 million in third-quarter 2014 were approximately 7 percent lower compared with $88 million a year ago.
Taxes other than income for domestic operations in third-quarter 2014 were $32 million vs. $27 million a year ago, driven by higher oil volumes.
Domestic depreciation, depletion and amortization expense was $201 million in third-quarter 2014, down 9 percent from $222 million a year ago primarily due to the previously discussed lower natural gas production volumes in 2014, partially offset by the impact of increased oil production which is at a higher rate per Mcfe.
Domestic general and administrative expenses were $71 million in third-quarter 2014 vs. $64 million in the same period a year ago, primarily attributable to $8 million of charges associated with an early exit program.
Domestic exploration expense was higher at $28 million in third-quarter 2014 compared with $21 million a year ago primarily due to impairments of exploratory leasehold and well costs.
CASH AND LIQUIDITY
Net cash provided by operating activities for the first nine months of 2014 was $779 million, up 50 percent vs. $520 million for the same period a year ago.
At Sept. 30, 2014, WPX had approximately $38 million in unrestricted domestic cash and cash equivalents and $27 million in international cash. WPX’s total domestic liquidity as of Sept. 30, 2014, was approximately $834 million under the company’s previous credit facility agreement.
Subsequent to the close of the third quarter, WPX executed a new five-year, $1.5 billion senior unsecured credit facility. The new agreement enhances the company’s liquidity position by gaining full access to the total commitments under the modified covenant structure.
DEVELOPMENT ACTIVITY
For the first three quarters of 2014, WPX participated in a total of 290 gross (247 net) wells in its continuing operations in the United States, including 253 gross operated wells in the company’s Williston, San Juan and Piceance basins.
Highlights for the company’s operated wells in its three core areas are provided below. The balance of gross (net) wells is accounted for in non-operated interests, as well as WPX’s own properties in other areas such as the Appalachia Basin.
In the Williston Basin, WPX completed 39 gross (36 net) wells in the first nine months of the year, including 14 gross (14 net) wells during the third quarter. The company has five rigs deployed on its Williston acreage.
In the San Juan Basin’s Gallup oil play, WPX completed 29 gross (25 net) wells in the first nine months of the year, including 16 gross (14 net) wells during the third quarter.
WPX now owns or controls 84,000 net acres in the Gallup oil window, an increase of 68 percent vs. the sequential quarter. The company added a third rig in the play during the third quarter.
In September, WPX beat its prior best drilling time in the Gallup by 21 percent, drilling a well in 9.5 days. The well had a total depth of 10,390 feet. WPX is now averaging 12.5 days on its Gallup wells from spud to rig release, an improvement of 25 percent vs. 16.6 days per well in the third quarter a year ago.
In the Piceance Basin, WPX completed 185 gross (180 net) wells in the first nine months of the year, including 68 gross (66 net) wells in the third quarter. WPX has nine rigs deployed in the Piceance.
A newly completed Niobrara horizontal well in the Piceance produced an initial high of 14 MMcf/d at a flowing pressure of 7,200 PSI. A second vertical test well is producing 2 MMcf/d, with the majority of production coming from horizons in the Mancos formation.
TOMORROW’S WEBCAST
WPX management will discuss its third-quarter 2014 results during a webcast starting at 10 a.m. Eastern tomorrow, Nov. 5. Participants can access the event via the homepage atwww.wpxenergy.com. The slides for the webcast are available for download today at the same website.
A limited number of phone lines also will be available at 877-415-3181. International callers should dial 857-244-7324. The conference identification code for both phone numbers is 53107806. A replay of the webcast will be available on WPX’s website for one year following the event.
FORM 10-Q
WPX plans to file its third-quarter Form 10-Q with the Securities and Exchange Commission this week. Once filed, the document will be available on both the SEC and WPX websites.
UPCOMING CONFERENCE PRESENTATION
WPX CEO Rick Muncrief is scheduled to speak at the Capital One Securities annual energy conference on Thursday, Dec. 11, at approximately 10:20 a.m. Eastern. Please visitwww.wpxenergy.com on the day of the event to confirm the time, see the slides and listen to the presentation.
About WPX Energy, Inc.
WPX Energy develops and operates oil and gas producing properties in North Dakota, New Mexico and Colorado. The company has a long history of innovation and stakeholder engagement, recognized through more than 40 local, state, federal and industry awards.
This press release includes “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the company expects, believes or anticipates will or may occur in the future are forward-looking statements. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the company. Statements regarding future drilling and production are subject to all of the risks and uncertainties normally incident to the exploration for and development and production of oil and gas. These risks include, but are not limited to, the volatility of oil, natural gas and NGL prices; uncertainties inherent in estimating oil, natural gas and NGL reserves; drilling risks; environmental risks; and political or regulatory changes. Investors are cautioned that any such statements are not guarantees of future performance and that actual results or developments may differ materially from those projected in the forward-looking statements. The forward-looking statements in this press release are made as of the date of this press release, even if subsequently made available by WPX Energy on its website or otherwise. WPX Energy does not undertake and expressly disclaims any obligation to update the forward-looking statements as a result of new information, future events or otherwise. Investors are urged to consider carefully the disclosure in our filings with the Securities and Exchange Commission, available from us at WPX Energy, Attn:Investor Relations, P.O. Box 21810, Tulsa, Okla., 74102, or from the SEC’s website atwww.sec.gov.
Additionally, the SEC requires oil and gas companies, in filings made with the SEC, to disclose proved reserves, which are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible – from a given date forward, from known reservoirs, under existing economic conditions, operating methods, and governmental regulations. The SEC permits the optional disclosure of probable and possible reserves. From time to time, we elect to use “probable” reserves and “possible” reserves, excluding their valuation. The SEC defines “probable” reserves as “those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.” The SEC defines“possible” reserves as “those additional reserves that are less certain to be recovered than probable reserves.” The Company has applied these definitions in estimating probable and possible reserves. Statements of reserves are only estimates and may not correspond to the ultimate quantities of oil and gas recovered. Any reserve estimates provided in this presentation that are not specifically designated as being estimates of proved reserves may include estimated reserves not necessarily calculated in accordance with, or contemplated by, the SEC‘s reserves reporting guidelines. Investors are urged to consider closely the disclosure in our SEC filings that may be accessed through the SEC’s website at www.sec.gov.
The SEC’s rules prohibit us from filing resource estimates. Our resource estimations include estimates of hydrocarbon quantities for (i) new areas for which we do not have sufficient information to date to classify as proved, probable or even possible reserves, (ii) other areas to take into account the low level of certainty of recovery of the resources and (iii) uneconomic proved, probable or possible reserves. Resource estimates do not take into account the certainty of resource recovery and are therefore not indicative of the expected future recovery and should not be relied upon. Resource estimates might never be recovered and are contingent on exploration success, technical improvements in drilling access, commerciality and other factors.
| WPX Energy, Inc. | ||||||||||||||||||||||||||||||||||||||||||||||||
| Consolidated | ||||||||||||||||||||||||||||||||||||||||||||||||
| (UNAUDITED) | ||||||||||||||||||||||||||||||||||||||||||||||||
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | YTD | |||||||||||||||||||||||||||||||||||||||
| Revenues: | ||||||||||||||||||||||||||||||||||||||||||||||||
| Product revenues: | ||||||||||||||||||||||||||||||||||||||||||||||||
|
Natural gas sales |
$ | 224 | $ | 265 | $ | 210 | $ | 216 | $ | 915 | $ | 322 | $ | 269 | $ | 207 | $ | 798 | ||||||||||||||||||||||||||||||
| Oil and condensate sales | 139 | 151 | 183 | 176 | 649 | 175 | 223 | 240 | 638 | |||||||||||||||||||||||||||||||||||||||
| Natural gas liquid sales | 54 | 58 | 57 | 61 | 230 | 61 | 55 | 54 | 170 | |||||||||||||||||||||||||||||||||||||||
| Total product revenues | 417 | 474 | 450 | 453 | 1,794 | 558 | 547 | 501 | 1,606 | |||||||||||||||||||||||||||||||||||||||
| Gas management | 261 | 205 | 176 | 249 | 891 | 561 | 231 | 145 | 937 | |||||||||||||||||||||||||||||||||||||||
| Net gain (loss) on derivatives not designated as hedges | (94 | ) | 78 | (15 | ) | (93 | ) | (124 | ) | (195 | ) | (17 | ) | 148 | (64 | ) | ||||||||||||||||||||||||||||||||
| Other | 4 | 7 | 5 | 6 | 22 | 1 | 5 | – | 6 | |||||||||||||||||||||||||||||||||||||||
| Total revenues | 588 | 764 | 616 | 615 | 2,583 | 925 | 766 | 794 | 2,485 | |||||||||||||||||||||||||||||||||||||||
| Costs and expenses: | ||||||||||||||||||||||||||||||||||||||||||||||||
| Lease and facility operating | 63 | 63 | 70 | 68 | 264 | 68 | 67 | 73 | 208 | |||||||||||||||||||||||||||||||||||||||
| Gathering, processing and transportation | 85 | 91 | 88 | 89 | 353 | 89 | 79 | 82 | 250 | |||||||||||||||||||||||||||||||||||||||
| Taxes other than income | 31 | 31 | 33 | 31 | 126 | 41 | 40 | 40 | 121 | |||||||||||||||||||||||||||||||||||||||
| Gas management, including charges for unutilized pipeline capacity | 243 | 222 | 201 | 265 | 931 | 391 | 233 | 164 | 788 | |||||||||||||||||||||||||||||||||||||||
| Exploration | 18 | 20 | 21 | 371 | 430 | 15 | 57 | 29 | 101 | |||||||||||||||||||||||||||||||||||||||
| Depreciation, depletion and amortization | 217 | 215 | 230 | 230 | 892 | 203 | 211 | 213 | 627 | |||||||||||||||||||||||||||||||||||||||
| Impairment of producing properties and costs of acquired unproved reserves | – | – | 19 | 844 | 863 | – | – | – | – | |||||||||||||||||||||||||||||||||||||||
| Loss on sale of working interests in the Piceance Basin | – | – | – | – | – | – | 195 | 1 | 196 | |||||||||||||||||||||||||||||||||||||||
| General and administrative | 70 | 72 | 67 | 74 | 283 | 71 | 73 | 75 | 219 | |||||||||||||||||||||||||||||||||||||||
| Other-net | 6 | 3 | 1 | 2 | 12 | 3 | 3 | 3 | 9 | |||||||||||||||||||||||||||||||||||||||
| Total costs and expenses | 733 | 717 | 730 | 1,974 | 4,154 | 881 | 958 | 680 | 2,519 | |||||||||||||||||||||||||||||||||||||||
| Operating income (loss) | (145 | ) | 47 | (114 | ) | (1,359 | ) | (1,571 | ) | 44 | (192 | ) | 114 | (34 | ) | |||||||||||||||||||||||||||||||||
| Interest expense | (26 | ) | (28 | ) | (28 | ) | (26 | ) | (108 | ) | (29 | ) | (28 | ) | (31 | ) | (88 | ) | ||||||||||||||||||||||||||||||
| Interest capitalized | – | – | 1 | – | 1 | – | – | 1 | 1 | |||||||||||||||||||||||||||||||||||||||
| Investment income, impairment of equity method investment and other | 5 | 8 | 4 | (16 | ) | 1 | 2 | 5 | 5 | 12 | ||||||||||||||||||||||||||||||||||||||
| Income (loss) from continuing operations before income taxes | $ | (166 | ) | $ | 27 | $ | (137 | ) | $ | (1,401 | ) | $ | (1,677 | ) | $ | 17 | $ | (215 | ) | $ | 89 | $ | (109 | ) | ||||||||||||||||||||||||
| Provision (benefit) for income taxes | (59 | ) | 9 | (29 | ) | (514 | ) | (593 | ) | 15 | (74 | ) | 28 | (31 | ) | |||||||||||||||||||||||||||||||||
| Income (loss) from continuing operations | $ | (107 | ) | $ | 18 | $ | (108 | ) | $ | (887 | ) | $ | (1,084 | ) | $ | 2 | $ | (141 | ) | $ | 61 | $ | (78 | ) | ||||||||||||||||||||||||
| Income (loss) from discontinued operations | (6 | ) | 4 | (8 | ) | (97 | ) | (107 | ) | 17 | 8 | 5 | 30 | |||||||||||||||||||||||||||||||||||
| Net income (loss) | $ | (113 | ) | $ | 22 | $ | (116 | ) | $ | (984 | ) | $ | (1,191 | ) | $ | 19 | $ | (133 | ) | $ | 66 | $ | (48 | ) | ||||||||||||||||||||||||
| Less: Net income (loss) attributable to noncontrolling interests | 3 | 4 | (2 | ) | (11 | ) | (6 | ) | 1 | 2 | 4 | 7 | ||||||||||||||||||||||||||||||||||||
| Net income (loss) attributable to WPX Energy, Inc. | $ | (116 | ) | $ | 18 | $ | (114 | ) | $ | (973 | ) | $ | (1,185 | ) | $ | 18 | $ | (135 | ) | $ | 62 | $ | (55 | ) | ||||||||||||||||||||||||
| Adjusted EBITDAX | ||||||||||||||||||||||||||||||||||||||||||||||||
| Reconciliation to net income (loss): | ||||||||||||||||||||||||||||||||||||||||||||||||
| Net income (loss) | $ | (113 | ) | $ | 22 | $ | (116 | ) | $ | (984 | ) | $ | (1,191 | ) | $ | 19 | $ | (133 | ) | $ | 66 | $ | (48 | ) | ||||||||||||||||||||||||
| Interest expense | 26 | 28 | 28 | 26 | 108 | 29 | 28 | 31 | 88 | |||||||||||||||||||||||||||||||||||||||
| Provision (benefit) for income taxes | (59 | ) | 9 | (29 | ) | (514 | ) | (593 | ) | 15 | (74 | ) | 28 | (31 | ) | |||||||||||||||||||||||||||||||||
| Depreciation, depletion and amortization | 217 | 215 | 230 | 230 | 892 | 203 | 211 | 213 | 627 | |||||||||||||||||||||||||||||||||||||||
| Exploration expenses | 18 | 20 | 21 | 371 | 430 | 15 | 57 | 29 | 101 | |||||||||||||||||||||||||||||||||||||||
| EBITDAX | 89 | 294 | 134 | (871 | ) | (354 | ) | 281 | 89 | 367 | 737 | |||||||||||||||||||||||||||||||||||||
| Impairment of producing properties, costs of acquired unproved reserves and equity investments | – | – | 19 | 864 | 883 | – | – | – | – | |||||||||||||||||||||||||||||||||||||||
| Loss on sale of working interests in the Piceance Basin | – | – | – | – | – | – | 195 | 1 | 196 | |||||||||||||||||||||||||||||||||||||||
| Net (gain) loss on derivatives not designated as hedges | 94 | (78 | ) | 15 | 93 | 124 | 195 | 17 | (148 | ) | 64 | |||||||||||||||||||||||||||||||||||||
| Net cash received (paid) related to settlement of derivatives not designated as hedges | 9 | (20 | ) | (2 | ) | (4 | ) | (17 | ) | (168 | ) | (17 | ) | 15 | (170 | ) | ||||||||||||||||||||||||||||||||
| (Income) loss from discontinued operations | 6 | (4 | ) | 8 | 97 | 107 | (17 | ) | (8 | ) | (5 | ) | (30 | ) | ||||||||||||||||||||||||||||||||||
| Adjusted EBITDAX | $ | 198 | $ | 192 | $ | 174 | $ | 179 | $ | 743 | $ | 291 | $ | 276 | $ | 230 | $ | 797 | ||||||||||||||||||||||||||||||
…
| WPX Energy, Inc. | ||||||||||||||||||||||||||||||||||||||||||||
| Domestic Segment | ||||||||||||||||||||||||||||||||||||||||||||
| (UNAUDITED) | ||||||||||||||||||||||||||||||||||||||||||||
| 2013 | 2014 | |||||||||||||||||||||||||||||||||||||||||||
| (Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | YTD | 1st Qtr | 2nd Qtr | 3rd Qtr | YTD | |||||||||||||||||||||||||||||||||||
| Revenues: | ||||||||||||||||||||||||||||||||||||||||||||
| Product revenues: | ||||||||||||||||||||||||||||||||||||||||||||
| Natural gas sales | $ | 220 | $ | 259 | $ | 206 | $ | 211 | $ | 896 | $ | 317 | $ | 262 | $ | 201 | $ | 780 | ||||||||||||||||||||||||||
| Oil and condensate sales | 111 | 121 | 154 | 148 | 534 | 149 | 194 | 199 | 542 | |||||||||||||||||||||||||||||||||||
| Natural gas liquid sales | 53 | 58 | 57 | 60 | 228 | 61 | 54 | 53 | 168 | |||||||||||||||||||||||||||||||||||
| Total product revenues | 384 | 438 | 417 | 419 | 1,658 | 527 | 510 | 453 | 1,490 | |||||||||||||||||||||||||||||||||||
| Gas management | 261 | 205 | 176 | 249 | 891 | 561 | 231 | 145 | 937 | |||||||||||||||||||||||||||||||||||
| Net gain (loss) on derivatives not designated as hedges | (94 | ) | 78 | (15 | ) | (93 | ) | (124 | ) | (195 | ) | (17 | ) | 148 | (64 | ) | ||||||||||||||||||||||||||||
| Other | 1 | 1 | 3 | 1 | 6 | 1 | 3 | 1 | 5 | |||||||||||||||||||||||||||||||||||
| Total revenues | 552 | 722 | 581 | 576 | 2,431 | 894 | 727 | 747 | 2,368 | |||||||||||||||||||||||||||||||||||
| Costs and expenses: | ||||||||||||||||||||||||||||||||||||||||||||
| Lease and facility operating | 55 | 53 | 62 | 57 | 227 | 60 | 59 | 63 | 182 | |||||||||||||||||||||||||||||||||||
| Gathering, processing and transportation | 84 | 90 | 88 | 88 | 350 | 89 | 78 | 82 | 249 | |||||||||||||||||||||||||||||||||||
| Taxes other than income | 25 | 25 | 27 | 25 | 102 | 35 | 33 | 32 | 100 | |||||||||||||||||||||||||||||||||||
| Gas management, including charges for unutilized pipeline capacity | 243 | 222 | 201 | 265 | 931 | 391 | 233 | 164 | 788 | |||||||||||||||||||||||||||||||||||
| Exploration | 17 | 17 | 21 | 368 | 423 | 15 | 54 | 28 | 97 | |||||||||||||||||||||||||||||||||||
| Depreciation, depletion and amortization | 210 | 205 | 222 | 221 | 858 | 193 | 202 | 201 | 596 | |||||||||||||||||||||||||||||||||||
| Impairment of producing properties and costs of acquired unproved reserves | – | – | 19 | 841 | 860 | – | – | – | – | |||||||||||||||||||||||||||||||||||
| Loss on sale of working interests in the Piceance Basin | – | – | – | – | – | – | 195 | 1 | 196 | |||||||||||||||||||||||||||||||||||
| General and administrative | 67 | 67 | 64 | 71 | 269 | 67 | 70 | 71 | 208 | |||||||||||||||||||||||||||||||||||
| Other-net | 5 | 7 | (2 | ) | 2 | 12 | 2 | 1 | 3 | 6 | ||||||||||||||||||||||||||||||||||
| Total costs and expenses | 706 | 686 | 702 | 1,938 | 4,032 | 852 | 925 | 645 | 2,422 | |||||||||||||||||||||||||||||||||||
| Operating income (loss) | (154 | ) | 36 | (121 | ) | (1,362 | ) | (1,601 | ) | 42 | (198 | ) | 102 | (54 | ) | |||||||||||||||||||||||||||||
| Interest expense | (26 | ) | (28 | ) | (28 | ) | (26 | ) | (108 | ) | (29 | ) | (28 | ) | (31 | ) | (88 | ) | ||||||||||||||||||||||||||
| Interest capitalized | – | – | 1 | – | 1 | – | – | 1 | 1 | |||||||||||||||||||||||||||||||||||
| Investment income, impairment of equity method investment and other | – | 1 | – | (21 | ) | (20 | ) | – | – | (1 | ) | (1 | ) | |||||||||||||||||||||||||||||||
| Income (loss) from continuing operations before income taxes | $ | (180 | ) | $ | 9 | $ | (148 | ) | $ | (1,409 | ) | $ | (1,728 | ) | $ | 13 | $ | (226 | ) | $ | 71 | $ | (142 | ) | ||||||||||||||||||||
| Summary of Production Volumes (1) | ||||||||||||||||||||||||||||||||||||||||||||
| Natural gas (MMcf) | 73,991 | 73,774 | 75,497 | 72,672 | 295,934 | 71,531 | 71,972 | 68,614 | 212,117 | |||||||||||||||||||||||||||||||||||
| Oil (MBbls) | 1,240 | 1,372 | 1,571 | 1,737 | 5,919 | 1,737 | 2,159 | 2,373 | 6,269 | |||||||||||||||||||||||||||||||||||
| Natural gas liquids (MBbls) | 1,904 | 1,893 | 1,810 | 1,808 | 7,415 | 1,587 | 1,625 | 1,574 | 4,786 | |||||||||||||||||||||||||||||||||||
| Combined equivalent volumes (MMcfe) (2) | 92,856 | 93,361 | 95,782 | 93,941 | 375,940 | 91,475 | 94,680 | 92,295 | 278,450 | |||||||||||||||||||||||||||||||||||
|
(1) Excludes our Powder River Basin operations, which were classified as discontinued operations. |
||||||||||||||||||||||||||||||||||||||||||||
|
(2) Oil and natural gas liquids were converted to MMcfe using the ratio of one barrel of oil, condensate or natural gas liquids to six thousand cubic feet of natural gas. |
||||||||||||||||||||||||||||||||||||||||||||
| Realized average price per unit, including the impact of hedges (1) | ||||||||||||||||||||||||||||||||||||||||||||
| Natural gas (per Mcf) | $ | 2.96 | $ | 3.53 | $ | 2.75 | $ | 2.88 | $ | 3.03 | $ | 4.42 | $ | 3.66 | $ | 2.92 | $ | 3.68 | ||||||||||||||||||||||||||
| Oil (per barrel) | $ | 89.78 | $ | 87.76 | $ | 97.94 | $ | 85.47 | $ | 90.22 | $ | 86.24 | $ | 89.24 | $ | 84.11 | $ | 86.47 | ||||||||||||||||||||||||||
| Natural gas liquids (per barrel) | $ | 28.26 | $ | 30.25 | $ | 31.20 | $ | 33.33 | $ | 30.72 | $ | 38.27 | $ | 33.58 | $ | 33.64 | $ | 35.16 | ||||||||||||||||||||||||||
|
(1) Excludes our Powder River Basin operations, which were classified as discontinued operations. |
||||||||||||||||||||||||||||||||||||||||||||
| Expenses per Mcfe (1) | ||||||||||||||||||||||||||||||||||||||||||||
| Lease and facility operating | $ | 0.59 | $ | 0.57 | $ | 0.64 | $ | 0.62 | $ | 0.60 | $ | 0.66 | $ | 0.63 | $ | 0.68 | $ | 0.65 | ||||||||||||||||||||||||||
| Gathering, processing and transportation | $ | 0.91 | $ | 0.96 | $ | 0.90 | $ | 0.95 | $ | 0.93 | $ | 0.97 | $ | 0.83 | $ | 0.89 | $ | 0.89 | ||||||||||||||||||||||||||
| Taxes other than income | $ | 0.27 | $ | 0.27 | $ | 0.28 | $ | 0.27 | $ | 0.27 | $ | 0.38 | $ | 0.35 | $ | 0.35 | $ | 0.36 | ||||||||||||||||||||||||||
| Depreciation, depletion and amortization | $ | 2.25 | $ | 2.21 | $ | 2.31 | $ | 2.35 | $ | 2.28 | $ | 2.11 | $ | 2.13 | $ | 2.18 | $ | 2.14 | ||||||||||||||||||||||||||
| General and administrative | $ | 0.72 | $ | 0.73 | $ | 0.66 | $ | 0.75 | $ | 0.71 | $ | 0.74 | $ | 0.73 | $ | 0.77 | $ | 0.75 | ||||||||||||||||||||||||||
|
(1) Excludes our Powder River Basin operations, which were classified as discontinued operations. |
||||||||||||||||||||||||||||||||||||||||||||
| Unutilized pipeline capacity | ||||||||||||||||||||||||||||||||||||||||||||
| Total unutilized pipeline capacity in gas management expense | $ | 13 | $ | 14 | $ | 17 | $ | 17 | $ | 61 | $ | 16 | $ | 12 | $ | 16 | $ | 44 | ||||||||||||||||||||||||||
| WPX Energy, Inc. | |||||||||||||||||||||||||||||||||
| International Segment | |||||||||||||||||||||||||||||||||
| (UNAUDITED) | |||||||||||||||||||||||||||||||||
| 2013 | 2014 | ||||||||||||||||||||||||||||||||
| (Dollars in millions) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | YTD | 1st Qtr | 2nd Qtr | 3rd Qtr | YTD | ||||||||||||||||||||||||
| Revenues: | |||||||||||||||||||||||||||||||||
| Product revenues: | |||||||||||||||||||||||||||||||||
| Natural gas sales | $ | 4 | $ | 6 | $ | 4 | $ | 5 | $ | 19 | $ | 5 | $ | 7 | $ | 6 | $ | 18 | |||||||||||||||
| Oil and condensate sales | 28 | 30 | 29 | 28 | 115 | 26 | 29 | 41 | 96 | ||||||||||||||||||||||||
| Natural gas liquid sales | 1 | – | – | 1 | 2 | – | 1 | 1 | 2 | ||||||||||||||||||||||||
| Total product revenues | 33 | 36 | 33 | 34 | 136 | 31 | 37 | 48 | 116 | ||||||||||||||||||||||||
| Gas management | – | – | – | – | – | – | – | – | – | ||||||||||||||||||||||||
| Net gain (loss) on derivatives not designated as hedges | – | – | – | – | – | – | – | – | – | ||||||||||||||||||||||||
| Other | 3 | 6 | 2 | 5 | 16 | – | 2 | (1 | ) | 1 | |||||||||||||||||||||||
| Total revenues | 36 | 42 | 35 | 39 | 152 | 31 | 39 | 47 | 117 | ||||||||||||||||||||||||
| Costs and expenses: | |||||||||||||||||||||||||||||||||
| Lease and facility operating | 8 | 10 | 8 | 11 | 37 | 8 | 8 | 10 | 26 | ||||||||||||||||||||||||
| Gathering, processing and transportation | 1 | 1 | – | 1 | 3 | – | 1 | – | 1 | ||||||||||||||||||||||||
| Taxes other than income | 6 | 6 | 6 | 6 | 24 | 6 | 7 | 8 | 21 | ||||||||||||||||||||||||
| Gas management, including charges for unutilized pipeline capacity | – | – | – | – | – | – | – | – | – | ||||||||||||||||||||||||
| Exploration | 1 | 3 | – | 3 | 7 | – | 3 | 1 | 4 | ||||||||||||||||||||||||
| Depreciation, depletion and amortization | 7 | 10 | 8 | 9 | 34 | 10 | 9 | 12 | 31 | ||||||||||||||||||||||||
| Impairment of producing properties | – | – | – | 3 | 3 | – | – | – | – | ||||||||||||||||||||||||
| Loss on sale of working interests in the Piceance Basin | – | – | – | – | – | – | – | – | – | ||||||||||||||||||||||||
| General and administrative | 3 | 5 | 3 | 3 | 14 | 4 | 3 | 4 | 11 | ||||||||||||||||||||||||
| Other-net | 1 | (4 | ) | 3 | – | – | 1 | 2 | – | 3 | |||||||||||||||||||||||
| Total costs and expenses | 27 | 31 | 28 | 36 | 122 | 29 | 33 | 35 | 97 | ||||||||||||||||||||||||
| Operating income (loss) | 9 | 11 | 7 | 3 | 30 | 2 | 6 | 12 | 20 | ||||||||||||||||||||||||
| Interest expense | – | – | – | – | – | – | – | – | – | ||||||||||||||||||||||||
| Interest capitalized | – | – | – | – | – | – | – | – | – | ||||||||||||||||||||||||
| Investment income and other | 5 | 7 | 4 | 5 | 21 | 2 | 5 | 6 | 13 | ||||||||||||||||||||||||
| Income (loss) from continuing operations before income taxes | $ | 14 | $ | 18 | $ | 11 | $ | 8 | $ | 51 | $ | 4 | $ | 11 | $ | 18 | $ | 33 | |||||||||||||||
| Summary of Net Production Volumes (1) | |||||||||||||||||||||||||||||||||
| Natural gas (MMcf) | 1,485 | 1,620 | 1,707 | 1,723 | 6,534 | 1,723 | 1,838 | 1,898 | 5,459 | ||||||||||||||||||||||||
| Oil (MBbls) | 506 | 553 | 484 | 489 | 2,032 | 466 | 475 | 598 | 1,539 | ||||||||||||||||||||||||
| Natural gas liquids (MBbls) | 42 | 44 | 42 | 40 | 167 | 41 | 40 | 40 | 121 | ||||||||||||||||||||||||
| Combined equivalent volumes (MMcfe)(2) | 4,775 | 5,202 | 4,862 | 4,894 | 19,733 | 4,766 | 4,927 | 5,728 | 15,422 | ||||||||||||||||||||||||
|
(1) Reflects approximately 69 percent of Apco’s production (which corresponds to our ownership interest in Apco) and other minor directly held interests. |
|||||||||||||||||||||||||||||||||
|
(2) Oil and natural gas liquids were converted to MMcfe using the ratio of one barrel of oil, condensate or natural gas liquids to six thousand cubic feet of natural gas. |
|||||||||||||||||||||||||||||||||
| WPX Energy, Inc. | |||||||||||||||||||||||||||||||||||||||||||
| Reconciliation- Adjusted Income (Loss) from Continuing Operations | |||||||||||||||||||||||||||||||||||||||||||
| (UNAUDITED) | |||||||||||||||||||||||||||||||||||||||||||
| 2013 | 2014 | ||||||||||||||||||||||||||||||||||||||||||
| (Dollars in millions, except per share amounts) | 1st Qtr | 2nd Qtr | 3rd Qtr | 4th Qtr | Year | 1st Qtr | 2nd Qtr | 3rd Qtr | YTD | ||||||||||||||||||||||||||||||||||
| Income (loss) from continuing operations attributable to WPX Energy, Inc. available to common stockholders | $ | (110 | ) | $ | 14 | $ | (106 | ) | $ | (876 | ) | $ | (1,078 | ) | $ | 1 | $ | (143 | ) | $ | 57 | $ | (85 | ) | |||||||||||||||||||
| Income (loss) from continuing operations – diluted earnings per share | $ | (0.55 | ) | $ | 0.07 | $ | (0.53 | ) | $ | (4.36 | ) | $ | (5.38 | ) | $ | 0.01 | $ | (0.71 | ) | $ | 0.28 | $ | (0.42 | ) | |||||||||||||||||||
| Pre-tax adjustments: | |||||||||||||||||||||||||||||||||||||||||||
| Impairment of producing properties, costs of acquired unproved reserves, leasehold and equity method investment (1) | $ | – | $ | – | $ | 19 | $ | 1,169 | $ | 1,188 | $ | – | $ | – | $ | – | $ | – | |||||||||||||||||||||||||
| Impairments- exploratory related | $ | – | $ | – | $ | – | $ | – | $ | – | $ | – | $ | 40 | $ | 22 | $ | 62 | |||||||||||||||||||||||||
| Loss on sale of working interests in the Piceance Basin | $ | – | $ | – | $ | – | $ | – | $ | – | $ | – | $ | 195 | $ | 1 | $ | 196 | |||||||||||||||||||||||||
| Expense related to Early Exit Program | $ | – | $ | – | $ | – | $ | – | $ | – | $ | – | $ | 2 | $ | 8 | $ | 10 | |||||||||||||||||||||||||
| Early rig release expenses | $ | – | $ | – | $ | – | $ | – | $ | – | $ | – | $ | – | $ | 6 | $ | 6 | |||||||||||||||||||||||||
| Costs related to chief executive officer separation | $ | – | $ | – | $ | – | $ | 4 | $ | 4 | $ | – | $ | – | $ | – | $ | – | |||||||||||||||||||||||||
| Buyout of transportation agreement | $ | – | $ | – | $ | – | $ | 9 | $ | 9 | $ | – | $ | – | $ | – | $ | – | |||||||||||||||||||||||||
| Unrealized MTM (gain) loss | $ | 103 | $ | (98 | ) | $ | 13 | $ | 89 | $ | 107 | $ | 27 | $ | – | $ | (133 | ) | $ | (106 | ) | ||||||||||||||||||||||
| Total pre-tax adjustments | $ | 103 | $ | (98 | ) | $ | 32 | $ | 1,271 | $ | 1,308 | $ | 27 | $ | 237 | $ | (96 | ) | $ | 168 | |||||||||||||||||||||||
| Less tax effect for above items | $ | (38 | ) | $ | 36 | $ | (12 | ) | $ | (463 | ) | $ | (477 | ) | $ | (10 | ) | $ | (87 | ) | $ | 35 | $ | (62 | ) | ||||||||||||||||||
| Impact of new Argentine capital tax law (1) | $ | – | $ | – | $ | 6 | $ | – | $ | 6 | $ | – | $ | – | $ | – | $ | – | |||||||||||||||||||||||||
| Impact of new state tax law in New York (net of federal benefit) | $ | – | $ | – | $ | – | $ | – | $ | – | $ | 9 | $ | – | $ | – | $ | 9 | |||||||||||||||||||||||||
| Total adjustments, after-tax | $ | 65 | $ | (62 | ) | $ | 26 | $ | 808 | $ | 837 | $ | 26 | $ | 150 | $ | (61 | ) | $ | 115 | |||||||||||||||||||||||
| Adjusted income (loss) from continuing operations available to common stockholders | $ | (45 | ) | $ | (48 | ) | $ | (80 | ) | $ | (68 | ) | $ | (241 | ) | $ | 27 | $ | 7 | $ | (4 | ) | $ | 30 | |||||||||||||||||||
| Adjusted diluted earnings (loss) per common share | $ | (0.22 | ) | $ | (0.24 | ) | $ | (0.39 | ) | $ | (0.35 | ) | $ | (1.20 | ) | $ | 0.13 | $ | 0.03 | $ | (0.02 | ) | $ | 0.14 | |||||||||||||||||||
| Diluted weighted-average shares (millions) | 199.9 | 203.8 | 200.7 | 200.9 | 200.4 | 205.2 | 202.7 | 207.5 | 202.5 | ||||||||||||||||||||||||||||||||||
| (1) These items are presented net of amounts attributable to noncontrolling interests. | |||||||||||||||||||||||||||||||||||||||||||
| WPX Energy, Inc. | |||||||||||||||||||||
| Consolidated Statement of Operations | |||||||||||||||||||||
| (Unaudited) | |||||||||||||||||||||
| Three months ended September 30, | Nine months ended September 30, | ||||||||||||||||||||
| 2014 | 2013 | 2014 | 2013 | ||||||||||||||||||
| (Millions, except per-share amounts) | |||||||||||||||||||||
| Revenues: | |||||||||||||||||||||
| Product revenues: | |||||||||||||||||||||
| Natural gas sales | $ | 207 | $ | 210 | $ | 798 | $ | 699 | |||||||||||||
| Oil and condensate sales | 240 | 183 | 638 | 473 | |||||||||||||||||
| Natural gas liquid sales | 54 | 57 | 170 | 169 | |||||||||||||||||
| Total product revenues | 501 | 450 | 1,606 | 1,341 | |||||||||||||||||
| Gas management | 145 | 176 | 937 | 642 | |||||||||||||||||
| Net gain (loss) on derivatives not designated as hedges | 148 | (15 | ) | (64 | ) | (31 | ) | ||||||||||||||
| Other | – | 5 | 6 | 16 | |||||||||||||||||
| Total revenues | 794 | 616 | 2,485 | 1,968 | |||||||||||||||||
| Costs and expenses: | |||||||||||||||||||||
| Lease and facility operating | 73 | 70 | 208 | 196 | |||||||||||||||||
| Gathering, processing and transportation | 82 | 88 | 250 | 264 | |||||||||||||||||
| Taxes other than income | 40 | 33 | 121 | 95 | |||||||||||||||||
| Gas management, including charges for unutilized pipeline capacity | 164 | 201 | 788 | 666 | |||||||||||||||||
| Exploration | 29 | 21 | 101 | 59 | |||||||||||||||||
| Depreciation, depletion and amortization | 213 | 230 | 627 | 662 | |||||||||||||||||
| Impairment of producing properties and costs of acquired unproved reserves | – | 19 | – | 19 | |||||||||||||||||
| Loss on sale of working interests in Piceance Basin | 1 | – | 196 | – | |||||||||||||||||
| General and administrative | 75 | 67 | 219 | 209 | |||||||||||||||||
| Other – net | 3 | 1 | 9 | 10 | |||||||||||||||||
| Total costs and expenses | 680 | 730 | 2,519 | 2,180 | |||||||||||||||||
| Operating income (loss) | 114 | (114 | ) | (34 | ) | (212 | ) | ||||||||||||||
| Interest expense | (31 | ) | (28 | ) | (88 | ) | (82 | ) | |||||||||||||
| Interest capitalized | 1 | 1 | 1 | 1 | |||||||||||||||||
| Investment income and other | 5 | 4 | 12 | 17 | |||||||||||||||||
| Income (loss) from continuing operations before income taxes | 89 | (137 | ) | (109 | ) | (276 | ) | ||||||||||||||
| Provision (benefit) for income taxes | 28 | (29 | ) | (31 | ) | (79 | ) | ||||||||||||||
| Income (loss) from continuing operations | 61 | (108 | ) | (78 | ) | (197 | ) | ||||||||||||||
| Income (loss) from discontinued operations | 5 | (8 | ) | 30 | (10 | ) | |||||||||||||||
| Net income (loss) | 66 | (116 | ) | (48 | ) | (207 | ) | ||||||||||||||
| Less: Net income (loss) attributable to noncontrolling interests | 4 | (2 | ) | 7 | 5 | ||||||||||||||||
| Net income (loss) attributable to WPX Energy, Inc. | $ | 62 | $ | (114 | ) | $ | (55 | ) | $ | (212 | ) | ||||||||||
| Amounts attributable to WPX Energy, Inc.: | |||||||||||||||||||||
| Basic Earnings (loss) per common share: | |||||||||||||||||||||
| Income (loss) from continuing operations | $ | 0.28 | $ | (0.53 | ) | $ | (0.42 | ) | $ | (1.01 | ) | ||||||||||
| Income (loss) from discontinued operations | 0.02 | (0.04 | ) | 0.15 | (0.05 | ) | |||||||||||||||
| Net income (loss) | $ | 0.30 | $ | (0.57 | ) | $ | (0.27 | ) | $ | (1.06 | ) | ||||||||||
| Basic weighted-average shares (millions) | 203.3 | 200.7 | 202.5 | 200.3 | |||||||||||||||||
| Diluted Earnings (loss) per common share: | |||||||||||||||||||||
| Income (loss) from continuing operations | $ | 0.28 | $ | (0.53 | ) | $ | (0.42 | ) | $ | (1.01 | ) | ||||||||||
| Income (loss) from discontinued operations | 0.02 | (0.04 | ) | 0.15 | (0.05 | ) | |||||||||||||||
| Net income (loss) | $ | 0.30 | $ | (0.57 | ) | $ | (0.27 | ) | $ | (1.06 | ) | ||||||||||
| Diluted weighted-average shares (millions) | 207.5 | 200.7 | 202.5 | 200.3 | |||||||||||||||||
| WPX Energy, Inc. | |||||||||||
| Consolidated Balance Sheet | |||||||||||
| (Unaudited) | |||||||||||
| September 30, 2014 | December 31, 2013 | ||||||||||
| ASSETS | (Millions) | ||||||||||
| Current assets: | |||||||||||
| Cash and cash equivalents | $ | 65 | $ | 99 | |||||||
| Accounts receivable, net of allowance of $6 million at September 30, 2014 and $7 million at December 31, 2013 | 465 | 536 | |||||||||
| Deferred income taxes | 31 | 49 | |||||||||
| Derivative assets | 107 | 50 | |||||||||
| Inventories | 70 | 71 | |||||||||
| Margin deposits | 52 | 71 | |||||||||
| Assets classified as held for sale | 184 | 1 | |||||||||
| Other | 31 | 45 | |||||||||
| Total current assets | 1,005 | 922 | |||||||||
| Investments | 135 | 129 | |||||||||
| Properties and equipment (successful efforts method of accounting) | 11,993 | 12,519 | |||||||||
| Less: Accumulated depreciation, depletion and amortization | (4,956 | ) | (5,445 | ) | |||||||
| Properties and equipment, net | 7,037 | 7,074 | |||||||||
| Derivative assets | 22 | 7 | |||||||||
| Other noncurrent assets | 45 | 297 | |||||||||
| Total assets | $ | 8,244 | $ | 8,429 | |||||||
| LIABILITIES AND EQUITY | |||||||||||
| Current liabilities: | |||||||||||
| Accounts payable | $ | 699 | $ | 652 | |||||||
| Accrued and other current liabilities | 175 | 187 | |||||||||
| Liabilities associated with assets held for sale | 50 | 3 | |||||||||
| Customer margin deposits payable | 14 | 55 | |||||||||
| Deferred income taxes | 1 | – | |||||||||
| Derivative liabilities | 72 | 110 | |||||||||
| Total current liabilities | 1,011 | 1,007 | |||||||||
| Deferred income taxes | 713 | 788 | |||||||||
| Long-term debt | 2,047 | 1,916 | |||||||||
| Derivative liabilities | 15 | 12 | |||||||||
| Asset retirement obligations | 199 | 310 | |||||||||
| Other noncurrent liabilities | 57 | 186 | |||||||||
| Equity: | |||||||||||
| Stockholders’ equity: | |||||||||||
| Preferred Stock (100 million shares authorized at $0.01 par value; no shares issued) | – | – | |||||||||
| Common Stock (2 billion shares authorized at $0.01 par value; 203.4 million shares issued at September 30, 2014 and 201 million shares issued at December 31, 2013) | 2 | 2 | |||||||||
| Additional paid-in-capital | 5,556 | 5,516 | |||||||||
| Accumulated deficit | (1,463 | ) | (1,408 | ) | |||||||
| Accumulated other comprehensive income (loss) | (1 | ) | (1 | ) | |||||||
| Total stockholders’ equity | 4,094 | 4,109 | |||||||||
| Noncontrolling interests in consolidated subsidiaries | 108 | 101 | |||||||||
| Total equity | 4,202 | 4,210 | |||||||||
| Total liabilities and equity | $ | 8,244 | $ | 8,429 | |||||||
| WPX Energy, Inc. | |||||||||||
| Consolidated Statement of Cash Flows | |||||||||||
| (Unaudited) | |||||||||||
| Nine months ended September 30, | |||||||||||
| 2014 | 2013 | ||||||||||
| (Millions) | |||||||||||
| Operating Activities | |||||||||||
| Net income (loss) | $ | (48 | ) | $ | (207 | ) | |||||
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |||||||||||
| Depreciation, depletion and amortization | 638 | 699 | |||||||||
| Deferred income tax provision (benefit) | (55 | ) | (67 | ) | |||||||
| Provision for impairment of properties and equipment (including certain exploration expenses) | 95 | 64 | |||||||||
| Amortization of stock-based awards | 26 | 24 | |||||||||
| (Gain) loss on sale of assets | 195 | (5 | ) | ||||||||
| Cash provided (used) by operating assets and liabilities: | |||||||||||
| Accounts receivable | 71 | 55 | |||||||||
| Inventories | 1 | (5 | ) | ||||||||
| Margin deposits and customer margin deposits payable | (22 | ) | (2 | ) | |||||||
| Other current assets | 16 | (11 | ) | ||||||||
| Accounts payable | (15 | ) | (5 | ) | |||||||
| Accrued and other current liabilities | (22 | ) | (32 | ) | |||||||
| Changes in current and noncurrent derivative assets and liabilities | (106 | ) | 18 | ||||||||
| Other, including changes in other noncurrent assets and liabilities | 5 | (6 | ) | ||||||||
| Net cash provided by operating activities | 779 | 520 | |||||||||
| Investing Activities | |||||||||||
| Capital expenditures (a) | (1,325 | ) | (843 | ) | |||||||
| Proceeds from sales of assets (b) | 389 | 10 | |||||||||
| Other | (3 | ) | (3 | ) | |||||||
| Net cash used in investing activities | (939 | ) | (836 | ) | |||||||
| Financing Activities | |||||||||||
| Proceeds from common stock | 15 | 4 | |||||||||
| Proceeds from long-term debt | 500 | – | |||||||||
| Borrowings on credit facility | 1,451 | 605 | |||||||||
| Payments on credit facility | (1,816 | ) | (335 | ) | |||||||
| Payments for debt issuance costs | (6 | ) | – | ||||||||
| Other | (12 | ) | (1 | ) | |||||||
| Net cash provided by financing activities | 132 | 273 | |||||||||
| Net increase (decrease) in cash and cash equivalents | (28 | ) | (43 | ) | |||||||
| Effect of exchange rate changes on cash and cash equivalents | (6 | ) | (2 | ) | |||||||
| Cash and cash equivalents at beginning of period | 99 | 153 | |||||||||
| Cash and cash equivalents at end of period | $ | 65 | $ | 108 | |||||||
|
_________ |
|||||||||||
| (a) Increase to properties and equipment | $ | (1,389 | ) | $ | (864 | ) | |||||
| Changes in related accounts payable and accounts receivable | 64 | 21 | |||||||||
| Capital expenditures | $ | (1,325 | ) | $ | (843 | ) | |||||
| (b) Proceeds in 2014 primarily relate to the sale of a portion of our working interests in the Piceance Basin and are subject to post-closing adjustments. | |||||||||||
