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WPX Energy Reports 2013 Results

2/27/2014

TULSA, Okla. – WPX Energy (NYSE:WPX) today announced its unaudited operating and financial results for the fourth quarter and the year ended Dec. 31, 2013.

Operating achievements during the year include a 39 percent increase in Williston Basin oil production, 534 Bcfe of domestic reserves additions, early development of the company’s oil discovery in the San Juan Basin’s Gallup Sandstone and initial delineation drilling of the Niobrara natural gas discovery in the Piceance Basin.

WPX’s 2013 financial results reflect a 14 percent decrease in consolidated gathering, processing and transportation expense and 32 percent growth in oil revenues, offset by the impact of previously disclosed non-cash impairment charges of approximately $1.4 billion that primarily occurred in the fourth quarter.

 

FULL YEAR 2013 FINANCIAL RESULTS

WPX reported an unaudited net loss attributable to WPX Energy of $1,185 million for full-year 2013, or a loss of $5.91 per share on a diluted basis, compared with a net loss of $223 million, or a loss of $1.12 per share, in 2012.

A 32 percent increase in consolidated oil revenues, lower gathering, processing and transportation costs, and a $36 million gain on the sale of Powder River deep rights leasehold was more than offset by a 20 percent decline in natural gas revenues, a 23 percent decline in NGL revenues, and the impact of non-cash impairments of approximately $1.4 billion, including a related charge to exploration expense.

The net loss from continuing operations attributable to WPX Energy was $1,185 million in 2013, or a loss of $5.91 per share on a diluted basis, compared with a net loss of $245 million, or a loss of $1.23 per share, in 2012. 

The non-cash impairments were primarily recorded in fourth-quarter 2013, reflecting impairments of producing properties, costs of acquired unproved reserves, unproved leasehold costs and an equity method investment. For 2013, these charges totaled $1,392 million, including $317 million recorded in exploration expense and $20 million in investment income. By comparison, WPX recorded $225 million of impairments in 2012.

Significant declines in forward natural gas prices, particularly Northeast index prices, were the primary factors for the 2013 impairments. Appalachia pricing declined 26 percent in the fourth quarter and 34 percent overall during 2013. NYMEX forward pricing also declined 18 percent throughout 2013.

Approximately $1.1 billion of the estimated charges relate to Appalachian properties, with the majority of the remaining balance attributable to Powder River properties. Significant judgment and assumptions in these assessments include estimates of reserve quantities, estimates of future commodity prices, drilling plans, expected capital costs and the company’s estimate of an applicable discount rate commensurate with the risk of the underlying cash flow estimates.

Full-year 2013 results also reflect the absence of $423 million of gains realized in 2012 on natural gas derivatives designated as hedges for accounting purposes and $202 million unfavorable change in derivatives not designated as hedges.

Excluding these charges and unrealized mark-to-market gains (losses), WPX had an adjusted loss from continuing operations of $244 million, or a loss of $1.22 per share on a diluted basis, in 2013 compared with an adjusted loss from continuing operations of $123 million, or a loss of $0.62 per share, in 2012. A reconciliation accompanies this press release.

The domestic net realized average price for natural gas including hedge impact was $2.99 per Mcf in 2013, down 11.5 percent from $3.38 per Mcf a year ago.

The net realized average price for domestic oil was $90.21 per barrel in 2013, an increase of 5 percent from $85.58 per barrel a year ago. The 2012 period is inclusive of hedges.

The domestic net realized average price for NGL was $30.70 per barrel in 2013, up 7.5 percent from $28.56 per barrel a year ago.

 

FOURTH-QUARTER 2013 FINANCIAL RESULTS

WPX reported an unaudited net loss attributable to WPX Energy of $973 million for fourth-quarter 2013, or a loss of $4.85 per share on a diluted basis, compared with a net loss of $106 million, or a loss of $0.53 per share, in the same period in 2012.

The net loss from continuing operations attributable to WPX Energy was $973 million in fourth-quarter 2013, or a loss of $4.85 per share on a diluted basis, vs. a loss of $105 million, or a loss of $0.53 per share, for the fourth quarter of 2012.

Fourth-quarter 2013 results were impacted by the previously mentioned non-cash impairment charges, which more than offset a 21 percent increase in oil revenues and the gain on the sale of Powder River deep rights leasehold.

Excluding these charges and unrealized mark-to-market gains (losses), WPX had an adjusted loss from continuing operations of $66 million, or a loss of $0.34 per share on a diluted basis, for fourth-quarter 2013, compared with an adjusted loss from continuing operations of $39 million, or a loss of $0.20 per share, for the same period in 2012. A reconciliation accompanies this press release.

 

ADJUSTED EBITDAX

WPX’s adjusted EBITDAX (a non-GAAP measure) for full-year 2013 was $779 million, compared with $1 billion for the same measure in 2012. For fourth-quarter 2013, WPX had adjusted EBITDAX of $192 million, compared with $256 million for the same period in 2012.

The difference in year-over-year adjusted EBITDAX is primarily the result of lower product revenues, including hedges.

 

EBITDAX (non-GAAP)

Full Year

 

Fourth Quarter

 

2013

 

2012

 

2013

 

2012

 

millions

 

millions

 

millions

 

millions

Net income (loss)

($1,191)

 

($211)

 

($984)

 

($104)

Interest expense

$108

 

$102

 

$26

 

$25

Provision (benefit) for income taxes

($655)

 

($111)

 

($571)

 

($40)

Depreciation, depletion and amortization

$940

 

$966

 

$241

 

$247

Exploration expenses

$431

 

$83

 

$371

 

$23

EBITDAX

($367)

 

$829

 

($917)

 

$151

               

Impairments of producing properties, costs of acquired   unproved reserves and equity investments

$1,075

 

$225

 

$1,056

 

$108

(Gain) on sale of Powder River Basin deep rights leasehold

($36)

 

 

($36)

 

Net (gain) loss on derivatives not designated as hedges

$124

 

($78)

 

$93

 

($15)

Net cash received (paid) related to settlement of derivatives     not designated as hedges

($17)

 

$46

 

($4)

 

$11

(Income) loss from discontinued operations

 

($22)

 

 

$1

Adjusted EBITDAX

$779

 

$1,000

 

$192

 

$256

EBITDAX represents earnings before interest expense, income taxes, depreciation, depletion and amortization and exploration expenses. Adjusted EBITDAX includes adjustments for impairments, net (gain) loss on derivatives not designated as hedges, (gain) on the sale of leasehold, net cash received (paid) on settlement of derivatives not designated as hedges 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 are working to increase our cash flows and improve our results,” said Jim Bender, president and chief executive officer.

“This includes efforts on a variety of fronts, such as cost reductions and a continued commitment to pursue new efficiencies in our operating areas. We believe 2014 can be a transformational year as we achieve our objectives and complete our leadership transition.

“WPX has the experience to succeed. We have properties we can grow, led by 285 new Piceance gas wells and 91 new Williston and Gallup oil wells in our capital program. And we recognize that we need to execute crisply on our plans. We are focused on building confidence in WPX,” Bender added.

 

PRODUCTION

WPX’s overall domestic and international production for full-year 2013 was 1,258 MMcfe/d, down 9 percent from 1,386 MMcfe/d a year ago. The decrease was driven by lower gas volumes and lower NGL volumes, which was the result of lower ethane recovery rates.

 

Average Daily Production

Full Year

 

 

4Q

 
 

2013

 

2012

Change

 

2013

 

2012

Change

Natural gas (MMcf/d)

       

 

       

Piceance Basin

601

 

673

-11%

 

595

 

637

-7%

Appalachian Basin

83

 

63

32%

 

81

 

71

14%

Powder River Basin

174

 

208

-16%

 

163

 

195

-16%

San Juan Basin

117

 

132

-11%

 

104

 

138

-25%

International

18

 

19

-5%

 

19

 

19

0%

Other

10

 

10

0%

 

9

 

10

-10%

Subtotal (MMcf/d)

1,003

 

1,105

-9%

 

971

 

1,070

-9%

         

 

       
         

 

       

Oil (Mbbl/d)

       

 

       

Williston Basin

13.2

 

9.5

39%

 

15.1

 

11.4

32%

San Juan Basin

0.8

 

0.0

100%

 

1.5

 

0.0

100%

Piceance Basin

1.9

 

2.3

-17%

 

1.8

 

2.0

-10%

International

5.6

 

6.0

-7%

 

5.3

 

5.8

-9%

Other

0.3

 

0.2

50%

 

0.5

 

0.2

150%

Subtotal (Mbbl/d)

21.8

 

18.0

21%

 

24.2

 

19.4

25%

         

 

       

NGLs (Mbbl/d)

       

 

       

Piceance

19.1

 

27.5

-31%

 

18.1

 

23.1

-22%

International

0.5

 

0.5

0%

 

0.4

 

0.5

-20%

Other

1.2

 

0.9

33%

 

1.6

 

1.4

14%

Subtotal (Mbbl/d)

20.8

 

28.9

-28%

 

20.1

 

25.0

-20%

         

 

       

Total Production (MMcfe/d)

1,258

 

1,386

-9%

 

1,237

 

1,336

-7%

                   
       

Total natural gas production of 1,003 MMcf/d in 2013 also decreased 9 percent from 1,105 MMcf/d a year ago. Total NGL production decreased 28 percent from a year ago to an average of 20.8 Mbbl/d in 2013.

Piceance Basin production was 727 MMcfe/d during 2013, down 15 percent from 852 MMcfe/d in 2012. Lower ethane recovery rates from downstream processing plants contributed to the reduction in the equivalent gas rate. Production growth also was stunted early in 2013 by a reduced rig count (five) and late in the year by weather-related impacts and temporary infrastructure outages in the fourth quarter.

Oil production in the Williston Basin increased 39 percent to an average of 13,200 barrels per day for full-year 2013. Fourth-quarter 2013 Williston volumes were 15,100 barrels per day, up 32 percent from 11,400 barrels per day in fourth-quarter 2012. WPX met its year-end exit rate goal of 15,000 barrels per day.

Overall domestic oil production climbed 35 percent for full-year 2013 and 21 percent on a consolidated basis, which includes international volumes. During fourth-quarter 2013, WPX’s overall consolidated oil production climbed to 24,200 barrels per day.

 

EXPENSES

WPX’s domestic expenses were approximately 3 percent lower for full-year 2013 than 2012 on a basis that includes lease operating expense (LOE), gathering, processing and transportation expense (GP&T), taxes other than income, general and administrative (G&A), and depreciation, depletion and amortization (DD&A). 

Total domestic costs and expenses were 30 percent higher in 2013 over the prior year, primarily the result of the non-cash impairment charges including the charge to exploration expense. The non-cash impairments were approximately $1.4 billion.

WPX's domestic lease and facility operating expenses for full-year 2013 were $271 million vs. $251 million in 2012. The increase is primarily attributable to increased water disposal costs and an increase in oil production, primarily in the Williston Basin.

As expected, domestic gathering, processing and transportation charges decreased in 2013, down 15 percent to $430 million vs. $504 million in 2012. The decrease primarily related to new favorable contract terms for gathering and processing services in the Piceance Basin, as well as lower volumes.

Taxes other than income for domestic operations in 2013 were $117 million vs. $87 million in 2012, driven by an increase in natural gas prices (excluding derivatives), increased crude oil volumes and higher crude oil prices.

Domestic depreciation, depletion and amortization expense was $906 million in 2013, compared with $939 in 2012. The $33 million decrease is due to lower production volumes and an increase in the reserve base used in the calculation of the company’s DD&A rate, which was partially driven by an increase in the 12-month historical average commodity price.

Domestic general and administrative expenses were nearly flat year-over-year at $275 million in 2013 vs. $273 million in 2012.

Domestic exploration expense was $424 million in 2013, compared with $72 million in 2012. The higher exploration expense primarily relates to a $317 million impairment to fair value of leasehold in the Appalachian Basin in 2013, as well as higher leasehold amortization expense.

 

CASH AND LIQUIDITY

Net cash provided by operating activities for full-year 2013 was $636 million, including $118 million in the fourth quarter.

At Dec. 31, 2013, WPX had approximately $48 million in unrestricted domestic cash and cash equivalents and $51 million in international cash.

The company’s total domestic liquidity at the end of 2013 was approximately $1.1 billion after drawing $410 million from its $1.5 billion revolving credit agreement during the year.

 

DEVELOPMENT ACTIVITY

WPX made approximately $1.15 billion of capital investments during 2013, down 24 percent vs. 2012 and almost 27 percent lower than 2011. Decreased development activity was driven by capital discipline and lower commodity prices, resulting in lower production levels in most basins with the exception of the Williston Basin.

During 2013, WPX participated in 416 gross (330 net) wells in the United States, including 94 gross (78 net) in the fourth quarter. This figure represents the number of wells that were completed and began commercial delivery of production.

Highlights for the company’s operated wells in primary 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 Powder River basin.

In the Piceance Basin, WPX completed 250 gross (237 net) wells in 2013, including 58 gross (54 net) in the fourth quarter. Last year’s drilling program included four Niobrara test wells to begin delineating the original discovery well. Initial drilling thus far has validated the existence of a highly pressured continuous gas accumulation capable of producing pipeline-quality dry gas. Future drilling will focus on driving down drilling costs while optimizing completion techniques. 

During the fourth quarter, WPX also initiated 3D seismic acquisition in the Grand Valley field to aid in the company’s Niobrara delineation work. WPX expects to have processed data by the end of the first quarter, providing 70 percent seismic coverage of WPX’s acreage in the Piceance Valley.

In the Williston Basin, WPX completed 49 gross (36 net) wells in 2013, including 15 gross (10 net) in the fourth quarter. This compares with 41 gross (27 net) for full-year 2012. The 2013 drilling success also was achieved while utilizing two less rigs than in 2012, demonstrating the company’s efficiency progress in the basin.

During the fourth quarter, WPX completed another phase of its 50-mile Van Hook gathering system in the Williston, which is comprised of different pipes carrying fresh water, produced water, natural gas and oil. In October, WPX started up the high pressure pipeline that currently takes oil from 44 wells on 13 different pads to a centralized delivery/sales point. Current volumes on the system are approximately 7,500 barrels of oil per day, with plans to reach 14,000 barrels per day. At the current rate, this eliminates the need for approximately 77 trucks per day at a savings of approximately $2.00 per barrel. WPX is working to expand the oil gathering to all of its Van Hook pads.

In the San Juan Basin, WPX completed 13 gross (13 net) oil wells in its new Gallup Sandstone development. WPX’s first 13 Gallup oil wells have flowed – on average – at 388 barrels of oil per day over their first 30 days, or 475 barrels per day on an equivalent basis. The 13 wells had – on average – a peak rate of 727 barrels per day on an equivalent basis.

WPX has since added a second rig in the Gallup, which spud its first well on Feb. 6. The first rig recently finished drilling on a three-well pad, which represents WPX’s first pad drilling in the Gallup development. WPX now has the lease rights to roughly 44,000 net acres in the Gallup Sandstone following acreage acquisitions in late 2013 and early 2014.

In the Appalachian Basin, WPX completed 32 gross (24 net) wells in 2013, including 8 gross (5 net) in the fourth quarter. WPX has since halted its drilling activity in the basin after Appalachia pricing in forward markets declined 26 percent in the fourth quarter.

 

2013 PROVED RESERVES

Yesterday, WPX announced its domestic proved reserves at Dec. 31, 2013, were 4.76 trillion cubic feet equivalent based on 2013 commodity price averages. 

Domestic oil reserves increased 34 percent to 103 million barrels, exceeding the 100-million-barrel mark for the first time. The company added 534 Bcfe of proved domestic reserves in 2013 through drilling. WPX replaced domestic oil production at a rate of 547 percent and all domestic production at a rate of 162 percent.

Year-end 2013 domestic reserves reflect a mixture of 76 percent natural gas, 13 percent crude oil and 11 percent NGL. WPX’s press release about its 2013 proved reserves is available at www.wpxenergy.com.

 

2014 GUIDANCE

WPX announced a planned 2014 capital program of $1.47 billion (midpoint) on Feb. 10, with approximately 85 percent of spending allocated to Williston, Piceance and San Juan Gallup development.

More than half of WPX’s planned 2014 investments are in domestic oil properties, with funding for the development of 62 Williston Basin wells and 29 San Juan Gallup oil wells. WPX believes its planned oil growth could increase domestic oil revenues by approximately 27 percent from 2013 to 2014 based on $90 per barrel oil.

WPX’s production goal with its 2014 investments is to drive an estimated December exit rate of 1,310 MMcfe/d in total volumes, which is 5 percent higher than its 2013 exit rate. Oil and liquids are expected to account for 25 percent of WPX’s 2014 exit rate.

WPX expects to drill 376 gross operated wells in 2014 by deploying an average of 15 to 16 rigs. Compared with 2013, this represents a two-rig increase in the Piceance for a total of nine rigs, an increase of one rig in the Williston for a total of five, and an increase of one rig in the San Juan Gallup for a total of two. 

WPX’s development plan for the Piceance Basin includes approximately $75 million for up to 10 new Niobrara delineation wells.

WPX plans to eliminate the funding gap in its 2014 capital plan through means such as asset sales and the potential formation of an MLP.

TODAY’S CONFERENCE CALL

WPX management will discuss its 2013 results and 2014 outlook during a webcast starting at 10 a.m. Eastern today. Participants can access the audio and the slides for the event via the homepage at www.wpxenergy.com.

A limited number of phone lines also will be available at 800-299-8538. International callers should dial 617-786-2902. The conference identification code for both phone numbers is 42904814. A replay of the webcast will be available on WPX’s website for one year following the event.

Form 10-K

WPX plans to file its 2013 Form 10-K with the Securities and Exchange Commission today. Once filed, the document will be available on both the SEC and WPX websites.

Download Analyst Report

Download Financial Statements

 

About WPX Energy, Inc.

WPX Energy is an independent exploration and production company formed during a spinoff two years ago. Overall, WPX has more than 30 years of experience in its sector, with nearly 40 local, state and federal awards for efficiency, innovation and corporate social responsibility. The company is actively developing its domestic oil and gas reserves in North Dakota, Colorado and New Mexico.

# # #

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 at www.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.



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