Market Overview

WPX Energy Reports 2Q 2018 Results

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Oil volumes exceed forecast by roughly 5,000 barrels per day

  • 2Q oil volumes climbed to 80,800 bbl/d, 23% higher than 1Q
  • 2Q Delaware oil volumes grew 94% vs. year ago
  • 2Q Williston oil volumes up 39% vs. year ago
  • 2Q total liquids, including NGLs, were approximately 100,000 bbl/d
  • WPX raising 2018 oil guidance 3% to 78,000-82,000 bbl/d for
    full-year
  • Company has already more than replaced San Juan Basin oil volumes
    divested in 1Q

WPX Energy (NYSE:WPX) reported second-quarter oil volumes of 80,800
bbl/d from its operations in the Delaware and Williston basins, which
were approximately 5,000 bbl/d higher than expected.

The company now expects full-year oil volumes of 78,000-82,000 bbl/d for
2018, which is 3 percent higher than its original forecast of
75,000-80,000 bbl/d. Volume growth in the latter half of the year
primarily is expected to occur in the fourth quarter based on the timing
of anticipated first sales in the Williston Basin.

WPX reported an unaudited second-quarter 2018 net loss from continuing
operations available to common shareholders of $83 million, or a loss of
$0.21 per share on a diluted basis. The loss was driven by $154 million
of net losses associated with its hedge book resulting from higher
forward oil prices, along with a $71 million loss on extinguishment of
debt.

Adjusted net income from continuing operations in second-quarter 2018
was $23 million, or income of $0.06 per share. A reconciliation
accompanies this press release.

Over the past 12 months (2Q 2017 to 2Q 2018), WPX has increased unhedged
adjusted EBITDAX 235 percent excluding the impact of its San Juan Basin
operations that were divested.

CEO PERSPECTIVE

"During the second quarter, WPX continued to deliver strong results as
our produced volumes, especially crude oil, grew at an impressive rate,"
said Rick Muncrief, chairman and chief executive officer.

"In addition, we're reaping some of the best basis differentials in the
Permian Basin among our peers. We expect this to continue over the next
couple of years, which is an outcome of our pro-active midstream and
marketing strategy.

"The company's results also reflect significant headway on margin
expansion. This is a credit to our people, the quality of our assets and
our keen focus on discipline and execution.

"Along with peer-leading well results in both of our basins, our Permian
team has actively engaged in acreage swaps which give us the ability to
drill more long laterals. With that, we've nearly doubled our average
lateral lengths in the basin over the past three years. This has a
tremendous impact on returns for an asset with decades of development to
come," Muncrief added.

RECENT EVENTS

In July, WPX exercised its option to double its 12.5 percent ownership
interest in the Oryx II pipeline project to 25 percent, which has been
expanded from 400,0000 bbl/d to 650,000 bbl/d. WPX has 100,000 bbl/d of
firm crude oil capacity on the project that will deliver volumes from
the Delaware Basin to Midland and Crane.

Also in July, WPX entered into a crude oil marketing agreement for
Williston production through mid-2020 which provides the company with
the option to receive Cushing market pricing for up to 15,000 barrels
per day. It includes a location differential that represents a discount
to the applicable pipeline tariff.

During the second quarter, WPX repurchased approximately $900 million of
long-term debt through a series of tender offers while also issuing $500
million of new long-term notes due in 2026. WPX's total remaining
long-term debt is approximately $2.18 billion. The company's next
significant debt maturity does not occur until 2022.

As previously announced, WPX also amended its credit facility during the
second quarter resulting in an increase to total commitments from $1.2
billion to $1.5 billion; an increase to the borrowing base from $1.5
billion to $1.8 billion; and the maturity was extended to 2023.

DELAWARE BASIN HIGHLIGHTS

WPX's Delaware production averaged 74.4 Mboe/d in second-quarter 2018,
up 18 percent vs. first-quarter 2018 and 83 percent higher than the same
period a year ago.

WPX had 20 wells with first sales in the basin during the second
quarter, including 15 long laterals of at least 1.5 miles each. Most of
the activity occurred in the Wolfcamp A interval.

Seven 1.5-mile laterals on the Tucker Draw pad posted 24-hour highs
averaging more than 2,400 barrels of oil per day during initial
production on restricted flow. The Tucker Draw wells are averaging
approximately 1,200 barrels of oil per day for each well after 60 days
of production, with cumulative oil volumes approaching 500,000 barrels.
Cumulative production for the wells is roughly 1,000,000 Boe.

On the Lindsay pad, the 1.5-mile 10-3B-2H lateral posted a high of
approximately 3,600 barrels of oil per day during initial production
from the Wolfcamp X/Y interval. It produced nearly 50,000 barrels of oil
in its first 20 days. Cumulative production exceeds 85,000 Boe. WPX
increased cluster spacing and used 100 percent 100 mesh frac sand in the
completion design.

Average lateral lengths of 7,500 feet in the Delaware during 2018 are on
track to be approximately 20 percent longer than in 2017. WPX has now
roughly doubled its average lateral lengths in the Delaware since
entering the basin in 2015 via its acquisition of RKI E&P.

Progress continues at the Stateline gas plant in anticipation of initial
startup operations this month on the first of two 200 MMcf/d cryogenic
processing trains. This facility is part of WPX's 50/50 joint venture
with Howard Energy Partners. Volumes from the plant will flow to
WhiteWater Midstream's Agua Blanca pipeline that WPX has a 20 percent
stake in.

WILLISTON BASIN HIGHLIGHTS

Williston Basin production averaged 50.6 Mboe/d in second-quarter 2018,
up 28 percent vs. the most recent quarter and 45 percent higher than the
same period a year ago.

WPX completed 12 Williston wells during the second quarter, evenly split
between the Bakken and Three Forks formations. All of the wells are
two-mile laterals. Three of the wells were in the North Sunday Island
area.

The three new North Sunday Island wells on the Mandan North pad have
cumulative 90-day production of more than 530,000 Boe (81% oil). Initial
production highs averaged 4,326 Boe/d per well, with a high of 4,558
Boe/d on the Mandan North 13-24HB well.

Another well on the Mandan pad (13-24HA completed on March 30) has
posted an even higher IP than previously reported. Its new high for a
24-hour volume is 5,990 Boe/d, made possible by being the first of the
four 2018 wells on the pad to begin flowback. This well now has
cumulative production of more than 215,000 Boe (81% oil) after its first
100 days.

Five wells on the Mandaree South pad were part of WPX's second-quarter
completions. After 60 days, the wells have cumulative production of more
than 426,000 Boe (81% oil). Initial production highs averaged 2,714
Boe/d per well, with a high of 3,335 Boe/d on the Mandaree South 19-18HA
well.

Two other second-quarter completions on the Joseph Eagle pad posted
24-hour highs of 3,596 Boe/d and 3,465 Boe/d, each at 81 percent oil.

WPX's first two wells in the North Sunday Island area – the Hidatsa
North 14-23HX well and the Mandan North 13-24HW well – now have combined
cumulative production of more than 910,000 Boe (81% oil). The Hidatsa
well has been online for roughly 300 days. The Mandan well has been
online for roughly 260 days. The two wells are currently averaging more
than 1,500 Boe/d per well.

The 7-well Arikara pad in the North Sunday Island area that went online
during late first-quarter 2018 now has cumulative volumes of more than
1,445,000 Boe (81% oil) after roughly 130 days of production. The top
producer is the Arikara 15-22HB, with nearly 230,000 Boe after its first
130 days.

2Q FINANCIAL RESULTS

Oil and NGL sales of $504 million accounted for 97 percent of WPX's
second-quarter 2018 total product revenues of $520 million. Quarterly
oil sales grew 30 percent vs. the most recent quarter driven by higher
average prices and production volumes.

Total product revenues of $927 million during the first half of 2018
were 124 percent higher than $413 million in the first half of 2017. Oil
revenues of $828 million during the first half of 2018 were 135 percent
higher than the same period a year ago.

For the first half of the year, WPX posted a net loss from continuing
operations attributable to common shareholders of $113 million,
including $223 million of net pre-tax losses associated with its hedging
activities and a $71 million pre-tax loss on extinguishment of debt.

On a per-Boe basis, lease operating expenses, general and administrative
expenses, and interest expense all declined in second-quarter 2018 vs.
the most recent quarter and the same period a year ago.

Adjusted EBITDAX (a non-GAAP financial measure) for the second quarter
rose 133 percent to $287 million vs. the same period a year ago.
Reconciliations for non-GAAP financial measures are available in the
tables that accompany this press release.

Based on its second-quarter adjusted EBITDAX, WPX's annualized run rate
for net debt/EBITDAX is now 1.8x.

For the first half of 2018, adjusted EBITDAX was $487 million, or 134
percent higher than $208 million in the first half of 2017. The
improvement in adjusted EBITDAX is driven by higher production volumes
and higher prices, partially offset by higher realized losses on
derivatives.

The weighted average gross sales price – prior to revenue deductions –
was $64.04 per barrel for oil, $2.30 for natural gas and $24.15 per
barrel for NGL during second-quarter 2018.

WPX's total liquidity at the close of business on June 30, 2018, was
approximately $1.5 billion, including cash, cash equivalents and all of
its available revolver capacity with the exception of $65 million in
outstanding letters of credit.

Cash flow from operations, inclusive of hedge impact, in the first half
of 2018 was $428 million of which $283 million came in the second
quarter. Second-quarter cash flow was 136 percent higher than a year ago.

2Q PRODUCTION

Total production volumes of 125.0 Mboe/d in second-quarter 2018
increased 22 percent vs. first-quarter 2018 and were 65 percent higher
than the same period a year ago. Liquids volumes accounted for 80
percent of second-quarter 2018 production.

Oil volumes of 80,800 bbl/d were 23 percent higher than the most recent
quarter and 61 percent higher vs. the same period a year ago, led by a
94 percent increase in the Delaware Basin over the past 12 months.

Average Daily Production     2Q       1Q Sequential
2018     2017     Change 2018     Change
Oil (Mbbl/d)            
Delaware Basin 39.1 20.2 94 % 33.8 16 %
Williston Basin     41.7     30.1     39 % 32.0     30 %
Subtotal (Mbbl/d) 80.8 50.3 61 % 65.8 23 %
 
NGLs (Mbbl/d)
Delaware Basin 14.2 8.0 78 % 10.9 30 %

Williston Basin

    4.6     2.5     84 % 4.0     15 %
Subtotal (Mbbl/d) 18.8 10.5 79 % 14.9 26 %
 
Natural gas (MMcf/d)
Delaware Basin 126.7 75.1 69 % 111.2 14 %
Williston Basin     25.5     14.0     82 % 21.1     21 %
Subtotal (MMcf/d) 152.2 89.1 71 % 132.3 15 %
 
Total Production (Mboe/d) 125.0     75.7     65 % 102.7     22 %
 

Note: 2Q 2017 figures do not include volumes associated with assets
that have since been divested, including Appalachia and San Juan. The
chart is a true apples-to-apples comparison that shows how WPX is
developing its core properties.

WPX completed 32 gross operated wells (29 net) in its two core basins
during second-quarter 2018 and participated in another seven gross (1
net) non-operated wells in the Delaware Basin.

Capital spending during the second quarter was $355 million, including
$23 million in midstream development expenses and $5 million in land
purchases.

For the balance of 2018, WPX has 70,500 bbl/d of oil hedged at a
weighted average price of $53.94 per barrel; 129,158 MMBtu/d of natural
gas hedged at a weighted average price of $2.99 per MMBtu; and 12,100
bbl/d of NGL hedged. Hedge prices for NGL barrel components are included
in the appendix of the webcast slide deck at www.wpxenergy.com.

For 2019, WPX has 43,000 bbl/d of oil hedged at a weighted average price
of $53.55 per barrel and 48,470 MMBtu/d of natural gas hedged at a
weighted average price of $2.87 per MMBtu.

UPDATED 2018 GUIDANCE

WPX is raising its full-year 2018 oil production guidance to an average
of 78,000-82,000 bbl/d, up 3 percent from previous guidance of
75,000-80,000 bbl/d. Guidance for total equivalent production in 2018 is
now 122-130 Mboe/d, up from 117-126 Mboe/d.

The company also updated its 2018 capital spending forecast to
$1,300-$1,400 million, driven by additional investments for non-operated
wells, facilities and infrastructure in the Delaware Basin, along with
larger completions in the Williston Basin. WPX also raised its
projection for midstream equity investments to $70-$85 million.

Further details and information about WPX's updated 2018 guidance are
available in the second-quarter slide presentation at www.wpxenergy.com.

THURSDAY WEBCAST

The company's next webcast takes place on Aug. 2 beginning at 10 a.m.
Eastern. Investors are encouraged to access the event and the
corresponding slides at www.wpxenergy.com.

A limited number of phone lines also will be available at (833)
832-5123. International callers should dial (469) 565-9820. The
conference identification code is 8995306.

UPCOMING CONFERENCE PRESENTATIONS

WPX President and Chief Operating Officer Clay Gaspar is scheduled to
speak at the Enercom Oil and Gas Conference on Tuesday, Aug. 21, at 10
a.m. Eastern.

WPX CEO Rick Muncrief is scheduled to present at Barclays Capital CEO
Energy-Power Conference on Tuesday, Sept. 4, at 12:25 p.m. Eastern.

Please visit www.wpxenergy.com
on the day of each event to confirm the time, see the slides and listen
to the presentations.

FORM 10-Q

WPX plans to file its second-quarter 2018 Form 10-Q with the Securities
and Exchange Commission this week. Once filed, the document will be
available on the SEC and WPX websites.

About WPX Energy, Inc.

WPX is an independent energy producer with core positions in the Permian
and Williston basins. WPX's production is approximately 80 percent
oil/liquids and 20 percent natural gas. The company also has an emerging
infrastructure portfolio in the Permian Basin. Visit www.wpxenergy.com for
more information.

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.

 
 
WPX Energy, Inc.
Consolidated (GAAP)
(UNAUDITED)
                         
2017 2018
(Dollars in millions)   1st Qtr   2nd Qtr   3rd Qtr   4th Qtr   YTD     1st Qtr   2nd Qtr   YTD
Revenues:
Product revenues:
Oil sales $ 159 $ 194 $ 218 $ 308 $ 879 $ 360 $ 468 $ 828
Natural gas sales 17 16 13 21 67 17 16 33
Natural gas liquid sales   11       16       16       27       70     30       36       66  
Total product revenues 187 226 247 356 1,016 407 520 927
Net gain (loss) on derivatives 203 116 (106 ) (210 ) 3 (69 ) (154 ) (223 )
Commodity management 5 8 4 8 25 36 64 100
Other   -       -       -       1       1     -       -       -  
Total revenues 395 350 145 155 1,045 374 430 804
 
Costs and expenses:
Depreciation, depletion and amortization 113 141 133 155 542 161 197 358
Lease and facility operating 36 41 45 46 168 55 59 114
Gathering, processing and transportation (1) 5 6 5 8 24 18 20 38
Taxes other than income 13 19 19 28 79 30 41 71
Exploration 36 16 17 18 87 19 17 36
General and administrative 41 44 40 41 166 43 44 87
Commodity management 5 8 4 10 27 39 54 93
Net (gain) loss on sales of assets (31 ) (7 ) (112 ) (11 ) (161 ) 1 (1 ) -
Other-net   4       7       4       -       15     2       2       4  
Total costs and expenses 222 275 155 295 947 368 433 801
 
Operating income (loss) 173 75 (10 ) (140 ) 98 6 (3 ) 3
 
Interest expense (47 ) (46 ) (48 ) (47 ) (188 ) (46 ) (39 ) (85 )
Loss on extinguishment of debt - - (17 ) - (17 ) - (71 ) (71 )
Investment income (loss) and other   2       -       2       (1 )     3     (1 )     1       -  
Income (loss) from continuing operations before income taxes $ 128 $ 29 $ (73 ) $ (188 ) $ (104 ) $ (41 ) $ (112 ) $ (153 )
Provision (benefit) for income taxes   33       (298 )     305       (168 )     (128 )   (15 )     (33 )     (48 )
Income (loss) from continuing operations $ 95 $ 327 $ (378 ) $ (20 ) $ 24 $ (26 ) $ (79 ) $ (105 )
Income (loss) from discontinued operations   (3 )     (251 )     232       (18 )     (40 )   (89 )     (2 )     (91 )
Net income (loss) $ 92 $ 76 $ (146 ) $ (38 ) $ (16 ) $ (115 ) $ (81 ) $ (196 )
Less: Dividends on preferred stock   4       4       3       4       15     4       4       8  
 
Net income (loss) available to WPX Energy, Inc. common
stockholders
$ 88     $ 72     $ (149 )   $ (42 )   $ (31 ) $ (119 )   $ (85 )   $ (204 )
Amounts available to WPX Energy, Inc. common stockholders:
Income (loss) from continuing operations $ 91 $ 323 $ (381 ) $ (24 ) $ 9 $ (30 ) $ (83 ) $ (113 )
Income (loss) from discontinued operations   (3 )     (251 )     232       (18 )     (40 )   (89 )     (2 )     (91 )
Net income (loss) $ 88     $ 72     $ (149 )   $ (42 )   $ (31 ) $ (119 )   $ (85 )   $ (204 )
 

(1)

2018 includes the impact of the application of ASC 606 with an
offset to product revenues.
           
Summary of Production Volumes (1)
Oil (MBbls) 3,504 4,572 4,973 5,915 18,964 5,920 7,352 13,271
Natural gas (MMcf) 7,747 8,357 7,946 11,261 35,311 11,908 13,854 25,763
Natural gas liquids (MBbls) 706 959 829 1,162 3,656 1,340 1,713 3,053
Combined equivalent volumes (MBoe) (2) 5,501 6,923 7,126 8,954 28,505 9,245 11,374 20,618
Per day volumes
Oil (MBbls/d) 38.9 50.2 54.1 64.3 52.0 65.8 80.8 73.3
Natural gas (MMcf/d) 86 92 86 122 97 132 152 142
Natural gas liquids (MBbls/d) 7.8 10.5 9.0 12.6 10.0 14.9 18.8 16.9
Combined equivalent volumes (Mboe/d) (2) 61.1 76.1 77.5 97.3 78.1 102.7 125.0 113.9
 
(1) Excludes activity classified as discontinued operations.
(2) Mboe is converted 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 (1)
Oil (per barrel) $ 45.32 $ 42.65 $ 43.74 $ 52.04 $ 46.36 $ 60.91 $ 63.63 $ 62.42
Natural gas (per Mcf) $ 2.18 $ 1.90 $ 1.67 $ 1.82 $ 1.89 $ 1.44 $ 1.12 $ 1.27
Natural gas liquids (per barrel) $ 16.31 $ 15.76 $ 19.28 $ 23.92 $ 19.26 $ 22.14 $ 20.94 $ 21.47
 
(1) Excludes activity classified as discontinued operations.
           
Expenses per Boe (1)
Depreciation, depletion and amortization $ 20.63 $ 20.26 $ 18.72 $ 17.34 $ 19.03 $ 17.38 $ 17.31 $ 17.34
Lease and facility operating $ 6.57 $ 5.92 $ 6.29 $ 5.17 $ 5.90 $ 5.97 $ 5.20 $ 5.55
Gathering, processing and transportation $ 0.94 $ 0.80 $ 0.76 $ 0.83 $ 0.83 $ 1.93 $ 1.79 $ 1.85
Taxes other than income $ 2.41 $ 2.68 $ 2.77 $ 3.09 $ 2.78 $ 3.21 $ 3.67 $ 3.46
General and administrative $ 7.38 $ 6.40 $ 5.62 $ 4.51 $ 5.80 $ 4.64 $ 3.89 $ 4.23
Interest expense $ 8.46 $ 6.75 $ 6.66 $ 5.32 $ 6.61 $ 4.95 $ 3.43 $ 4.11
 
(1) Excludes activity classified as discontinued operations.
     
 
 
WPX Energy, Inc.
Reconciliation of NON-GAAP Measures
(UNAUDITED)
                     
2017 2018
(Dollars in millions, except per share amounts)   1st Qtr   2nd Qtr   3rd Qtr   4th Qtr   Year       1st Qtr   2nd Qtr   YTD
Reconciliation of adjusted income (loss) from continuing
operations available to common stockholders:
Income (loss) from continuing operations available to WPX Energy,
Inc. common stockholders - reported
$ 91     $ 323     $ (381 )   $ (24 )   $ 9   $ (30 )   $ (83 )   $ (113 )
Pre-tax adjustments:
Impairments reported in exploration expense $ 23 $ - $ - $ - $ 23 $ - $ - $ -
Net (gain) loss on sales of assets $ (31 ) $ (7 ) $ (112 ) $ (11 ) $ (161 ) $ 1 $ (1 ) $ -
Loss on extinguishment of debt $ - $ - $ 17 $ - $ 17 $ - $ 71 $ 71
Unrealized MTM (gain) loss $ (208 )   $ (102 )   $ 120     $ 191     $ 1   $ 14     $ 76     $ 90  
Total pre-tax adjustments $ (216 ) $ (109 ) $ 25 $ 180 $ (120 ) $ 15 $ 146 $ 161
Less tax effect for above items $ 81 $ 41 $ (10 ) $ (68 ) $ 44 $ (3 ) $ (33 ) $ (37 )
Impact of state deferred tax rate change $ (6 ) $ - $ - $ (6 ) $ (12 ) $ (4 ) $ - $ (4 )
Impact of state tax valuation allowance (annual effective tax rate
method)
$ (6 ) $ (161 ) $ 171 $ (4 ) $ - $ - $ - $ -
Impact of federal rate change (a) $ - $ - $ - $ (83 ) $ (83 ) $ - $ - $ -
Adjustment for estimated annual effective tax rate method $ -     $ (148 )   $ 155     $ (7 )   $ -   $ -     $ (7 )   $ (7 )
Total adjustments, after tax $ (147 )   $ (377 )   $ 341     $ 12     $ (171 ) $ 8     $ 106     $ 113  
Adjusted income (loss) from continuing operations available to
common stockholders
$ (56 )   $ (54 )   $ (40 )   $ (12 )   $ (162 ) $ (22 )   $ 23     $ -  
 
  (a) Includes $92 million for the provisional impact of the Tax Cuts
and Jobs Act offset by the impact of the pre-tax adjustments above.
   
Reconciliation of adjusted diluted income (loss) per common share:
Income (loss) from continuing operations - diluted earnings per
share - reported
$ 0.23     $ 0.77     $ (0.96 )   $ (0.06 )   $ 0.02   $ (0.07 )   $ (0.21 )   $ (0.28 )
Impact of adjusted diluted weighted-average shares $ 0.01     $ 0.05     $ -     $ -     $ -   $ -     $ 0.01     $ -  
Pretax adjustments (b):
Impairments reported in exploration expense $ 0.06 $ - $ - $ - $ 0.06 $ - $ - $ -
Net (gain) loss on sales of assets $ (0.08 ) $ (0.02 ) $ (0.28 ) $ (0.03 ) $ (0.41 ) $ - $ - $ -
Loss on extinguishment of debt $ - $ - $ 0.04 $ - $ 0.04 $ - $ 0.18 $ 0.18
Unrealized MTM (gain) loss $ (0.54 )   $ (0.26 )   $ 0.30     $ 0.48     $ -   $ 0.04     $ 0.18     $ 0.22  
Total pretax adjustments $ (0.56 ) $ (0.28 ) $ 0.06 $ 0.45 $ (0.31 ) $ 0.04 $ 0.36 $ 0.40
Less tax effect for above items $ 0.20 $ 0.10 $ (0.02 ) $ (0.18 ) $ 0.12 $ (0.02 ) $ (0.08 ) $ (0.09 )
Impact of state tax rate change $ (0.01 ) $ - $ - $ (0.02 ) $ (0.03 ) $ (0.01 ) $ - $ (0.01 )
Impact of state valuation allowance (annual effective tax rate
method)
$ (0.02 ) $ (0.40 ) $ 0.43 $ 0.01 $ - $ - $ - $ -
Impact of federal rate change $ - $ - $ - $ (0.21 ) $ (0.21 ) $ - $ - $ -
Adjustment for estimated annual effective tax rate method $ -     $ (0.37 )   $ 0.39     $ (0.02 )   $ -   $ -     $ (0.02 )   $ (0.02 )
Total adjustments, after-tax $ (0.39 )   $ (0.95 )   $ 0.86     $ 0.03     $ (0.43 ) $ 0.01     $ 0.26     $ 0.28  
Adjusted diluted income (loss) per common share $ (0.15 )   $ (0.13 )   $ (0.10 )   $ (0.03 )   $ (0.41 ) $ (0.06 )   $ 0.06     $ -  
Reported diluted weighted-average shares (millions) 410.4 423.2 398.1 398.2 397.4 398.6 400.0 399.3
Effect of dilutive securities due to adjusted income (loss) from
continuing operations available to common stockholders
  (24.1 )     (25.4 )     -       -       (2.3 )   -       3.1       3.2  
Adjusted diluted weighted-average shares (millions)   386.3       397.8       398.1       398.2       395.1     398.6       403.1       402.5  
 
  (b) Per share impact is based on adjusted diluted weighted-average
shares.
   
 
Reconciliation of Adjusted EBITDAX
Net income (loss) - reported $ 92 $ 76 $ (146 ) $ (38 ) $ (16 ) $ (115 ) $ (81 ) $ (196 )
Interest expense 47 46 48 47 188 46 39 85
Provision (benefit) for income taxes 33 (298 ) 305 (168 ) (128 ) (15 ) (33 ) (48 )
Depreciation, depletion and amortization 113 141 133 155 542 161 197 358
Exploration expenses   36       16       17       18       87     19       17       36  
EBITDAX 321 (19 ) 357 14 673 96 139 235
Net (gain) loss on sales of assets (31 ) (7 ) (112 ) (11 ) (161 ) 1 (1 ) -
Loss on extinguishment of debt - - 17 - 17 - 71 71
Net (gain) loss on derivatives (203 ) (116 ) 106 210 (3 ) 69 154 223
Net cash received (paid) related to settlement of derivatives (5 ) 14 14 (19 ) 4 (55 ) (78 ) (133 )
(Income) loss from discontinued operations   3       251       (232 )     18       40     89       2       91  
Adjusted EBITDAX $ 85     $ 123     $ 150     $ 212     $ 570   $ 200     $ 287     $ 487  
   
 
 
WPX Energy, Inc.
Consolidated Statements of Operations
(Unaudited)
                 
Three months ended June 30, Six months ended June 30,
2018 2017 2018 2017
(Millions, except per share amounts)
Revenues:
Product revenues:
Oil sales $ 468 $ 194 $ 828 $ 353
Natural gas sales 16 16 33 33
Natural gas liquid sales   36     16     66     27  
Total product revenues 520 226 927 413
Net gain (loss) on derivatives (154 ) 116 (223 ) 319
Commodity management   64     8     100     13  
Total revenues 430 350 804 745
Costs and expenses:
Depreciation, depletion and amortization 197 141 358 254
Lease and facility operating 59 41 114 77
Gathering, processing and transportation 20 6 38 11
Taxes other than income 41 19 71 32
Exploration 17 16 36 52
General and administrative (including equity-based compensation of
$10 million, $8 million, $17 million and $15 million for the
respective periods)
44 44 87 85
Commodity management 54 8 93 13
Net gain on sales of assets (1 ) (7 ) - (38 )
Other - net   2     7     4     11  
Total costs and expenses   433     275     801     497  
 
Operating income (loss) (3 ) 75 3 248
Interest expense (39 ) (46 ) (85 ) (93 )
Loss on extinguishment of debt (71 ) - (71 ) -
Investment income (loss) and other   1     -     -     2  
Income (loss) from continuing operations before income taxes (112 ) 29 (153 ) 157
Benefit for income taxes   (33 )   (298 )   (48 )   (265 )
Income (loss) from continuing operations (79 ) 327 (105 ) 422
Loss from discontinued operations   (2 )   (251 )   (91 )   (254 )
Net income (loss) (81 ) 76 (196 ) 168
Less: Dividends on preferred stock   4     4     8     8  
Net income (loss) available to WPX Energy, Inc. common stockholders $ (85 ) $ 72   $ (204 ) $ 160  
 
Amounts available to WPX Energy, Inc. common stockholders:
Income (loss) from continuing operations $ (83 ) $ 323 $ (113 ) $ 414
Loss from discontinued operations   (2 )   (251 )   (91 )   (254 )
Net income (loss) $ (85 ) $ 72   $ (204 ) $ 160  
 
Basic earnings (loss) per common share:
Income (loss) from continuing operations $ (0.21 ) $ 0.81 $ (0.28 ) $ 1.06
Loss from discontinued operations   -     (0.63 )   (0.23 )   (0.65 )
Net income (loss) $ (0.21 ) $ 0.18   $ (0.51 ) $ 0.41  
 
Basic weighted-average shares 400.0 397.8 399.3 392.1
 
Diluted earnings (loss) per common share:
Income (loss) from continuing operations $ (0.21 ) $ 0.77 $ (0.28 ) $ 1.01
Loss from discontinued operations   -     (0.60 )   (0.23 )   (0.61 )
Net income (loss) $ (0.21 ) $ 0.17   $ (0.51 ) $ 0.40  
 
Diluted weighted-average shares 400.0 423.2 399.3 418.8
 
 
WPX Energy, Inc.
Consolidated Balance Sheets
(Unaudited)
       

June 30,
2018

December 31,
2017

ASSETS (Millions)
Current assets:
Cash and cash equivalents $ 103 $ 189
Accounts receivable, net of allowance of $2 million as of June 30,
2018 and December 31, 2017
323 307
Derivative assets 136 36
Inventories 40 30
Assets classified as held for sale - 811
Other   26     28  
Total current assets 628 1,401
Investments 92 70
Properties and equipment (successful efforts method of accounting) 9,314 8,674
Less: Accumulated depreciation, depletion and amortization   (2,340 )   (1,983 )
Properties and equipment, net 6,974 6,691
Derivative assets 49 23
Other noncurrent assets   27     22  
Total assets $ 7,770   $ 8,207  
 
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable $ 563 $ 446
Accrued and other current liabilities 148 209
Liabilities associated with assets held for sale - 20
Derivative liabilities   363     171  
Total current liabilities 1,074 846
Deferred income taxes 42 117
Long-term debt, net 2,154 2,575
Derivative liabilities 89 65
Asset retirement obligations 48 32
Other noncurrent liabilities 428 445
 
Equity:
Stockholders' equity:
Preferred stock (100 million shares authorized at $0.01 par value;
4.8 million shares outstanding at June 30, 2018 and December 31,
2017)
232 232
Common stock (2 billion shares authorized at $0.01 par value; 400.3
million shares and 398.3 million shares issued and outstanding at
June 30, 2018 and December 31, 2017)
4 4
Additional paid-in-capital 7,483 7,479
Accumulated deficit   (3,784 )   (3,588 )
Total equity   3,935     4,127  
Total liabilities and equity $ 7,770   $ 8,207  
 
 
WPX Energy, Inc.
Consolidated Statements of Cash Flows
(Unaudited)
         
Six Months ended June 30,
2018 2017
(Millions)
Operating Activities(a)
Net income (loss) $ (196 ) $ 168
Adjustments to reconcile net income (loss) to net cash provided by
operating activities:
Depreciation, depletion and amortization 365 318
Deferred income tax benefit (75 ) (24 )
Provision for impairment of properties and equipment (including
certain exploration expenses)
37 58
Net (gain) loss on derivatives 223 (319 )
Net settlements related to derivatives (133 ) 9
Amortization of stock-based awards 18 17
Loss on extinguishment of debt 71 -
Net (gain) loss on sales of assets including discontinued operations 151 (41 )
Cash provided (used) by operating assets and liabilities:
Accounts receivable (16 ) (49 )
Inventories (11 ) (3 )
Other current assets 4 (5 )
Accounts payable 73 72
Federal income taxes receivable - 12
Accrued and other current liabilities (59 ) (45 )
Liabilities accrued in prior years for retained transportation and
gathering contracts related to discontinued operations
(28 ) (29 )
Other, including changes in other noncurrent assets and liabilities   4     3  
Net cash provided by operating activities (a)   428     142  
 
Investing Activities(a)
Capital expenditures(b) (660 ) (542 )
Proceeds from sales of assets 686 38
Purchase of a business - (798 )
Purchase of investments   (23 )   (3 )
Net cash provided by (used in) investing activities (a)   3     (1,305 )
 
Financing Activities
Proceeds from common stock 5 671
Dividends paid on preferred stock (8 ) (7 )
Borrowings on credit facility 303 85
Payments on credit facility (303 ) (60 )
Proceeds from long-term debt, net of discount 494 -
Payments for retirement of long-term debt, including premium (986 ) -
Taxes paid for shares withheld (12 ) (10 )
Payments for debt issuance costs and credit facility amendment fees (10 ) -
Other   1     (1 )
Net cash provided by (used in) financing activities   (516 )   678  
 
Net decrease in cash and cash equivalents and restricted cash (85 ) (485 )
Cash and cash equivalents and restricted cash at beginning of period   201     506  
Cash and cash equivalents and restricted cash at end of period $ 116   $ 21  
   
(a) Amounts reflect continuing and discontinued operations unless
otherwise noted.
(b) Increase to properties and equipment $ (705 ) $ (596 )
Changes in related accounts payable and accounts receivable   45     54  
Capital expenditures $ (660 ) $ (542 )
 

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