WPX Energy Reports 2Q 2018 Results

WPX Energy Reports 2Q 2018 Results

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.

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
Media Contact:
Kelly Swan, 539-573-4944
or
Investor Contact:
David Sullivan, 539-573-9360

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