DALLAS, Feb. 27, 2017 /PRNewswire/ -- RSP Permian, Inc. ("RSP" or the "Company") (NYSE: RSPP) today reported financial and operating results for the quarter and year ended December 31, 2016, year-end 2016 proved reserves, 2017 guidance and 2018 and 2019 production outlook.  In addition, the Company filed its Annual Report on Form 10-K for the year ended December 31, 2016 with the Securities and Exchange Commission (the "SEC") and posted an updated presentation on its website at www.rsppermian.com.

Highlights for the Fourth Quarter and Full Year 2016:

• 4Q16 production increased 48% to 35.8 MBoe/d (71% oil, 88% liquids), compared to 4Q15
• Full year 2016 production increased 39% to 29.2 MBoe/d (73% oil, 89% liquids), compared to 2015
• 4Q16 net income of $1.4 million, or $0.01 per diluted share. Adjusted net income, which does not include certain items, was $13.4 million, or $0.10 per diluted share
• 4Q16 adjusted EBITDAX increased 22% to $90.5 million compared to 4Q15
• 4Q16 cash operating expenses of $9.11/Boe, 23% below 2015 average of $11.85
• 4Q16 development capital expenditures of $95.5 million
• Full year 2016 development capital expenditures of $294.2 million
• Entry into the Delaware Basin with previously announced $2.4 billion acquisition of Silver Hill Energy Partners, LLC ("SHEP I") and pending acquisition of Silver Hill E&P II, LLC ("SHEP II"), expected to close March 1, 2017
• Maintained strong year-end liquidity position and balance sheet, pro forma closing of SHEP II with $109 million of cash and no borrowings outstanding under revolving credit facility
  • Amended and restated credit facility, extending maturity date to December 2021, increasing borrowing base to $1.1 billion upon closing SHEP II, and increasing lender's commitments to $2.5 billion
• Pro forma proved reserves increased by 78% to 283 MMBoe⁽¹⁾ (70% oil, 88% liquids) over 2015
• Achieved low drill-bit finding and development cost of $4.05/Boe with an 848% reserve replacement ratio and a 684% organic reserve replacement ratio⁽²⁾

Recent Midland Basin Well Results

• Mask 1004/1005 two-well pad in Midland County: Two 9,500' lateral wells, targeting the Lower Spraberry and Wolfcamp B formations, flowed naturally producing almost 200,000 Boe before being put on electric submersible pump ("ESP") and establishing peak 30-day average rate of 2,932 Boe/d (73% oil)
• Spanish Trail 344 two-well pad and Spanish Trail 341 two-well pad: Four 6,500' lateral wells, with two wells each targeting the Wolfcamp A and Wolfcamp B formations, established a peak 30-day average rate of 6,212 Boe/d (79% oil) and produced in excess of 250,000 Boe in less than 60 days

2017 Guidance and 2018 and 2019 Production Outlook

• Average net daily production range of 53.0 - 57.0 MBoe/d in 2017, an 82% - 95% increase over 2016
• Development capital expenditure range of $625 - $700 million (drilling, completion, infrastructure and other) with drilling and completion of $575 - $625 million and infrastructure and other of $50 - $75 million
• 30%+ annual production growth profile in 2018 and 2019 with cash flow neutrality beginning in 2018 at $55 oil
• Expanded hedge profile covering 55% of 2017E oil production and 64% of 2017E natural gas volumes at the midpoint. Entered into basis swaps to protect Midland-Cushing differentials and began layering in 2018 oil hedges

Steve Gray, Chief Executive Officer, commented, "I am pleased to report our fourth quarter and full year results, highlighted by annual production growth of nearly 40% with 25% less in capital expenditures as compared to last year.  Importantly, we continued to operate efficiently with strong cash margins and record low drill-bit finding and development costs.  During the year, we reduced our activity levels in response to depressed oil prices early in the year and remained patient on M&A opportunities until we identified high quality properties that would compete for capital in our existing portfolio.  With our recent entry into the Delaware Basin through our $2.4 billion acquisition of Silver Hill, we believe we have assembled one of the most focused and highest returning asset bases in the Permian Basin, solidifying our ability to achieve outstanding growth and strong operating and capital efficiency for years to come."

Mr. Gray continued, "I am also pleased to announce that our shareholders have overwhelmingly approved our issuance of RSP common stock to partially fund the SHEP II transaction which we expect to close Wednesday.   We have already begun to integrate the Silver Hill assets into our inventory and are working towards achieving efficient, multi-zone horizontal development on the acquired properties.  In addition, we recently acquired the underlying water disposal infrastructure supporting our operations in the Delaware.  We are currently expanding these facilities and developing new facilities to support our growing operations and lower our operating costs.  We are also working diligently with our various midstream partners and expect to be in position to ramp our drilling program beginning in the second half of 2017.  Recent strong well results, which span five horizontal zones on the properties, highlight the attractive return profile in multiple stacked horizontal zones on our Delaware acreage position."

(1) Includes SHEP II.  Pro forma proved reserves prepared by Netherland Sewell & Associates, Inc. (NSAI).
(2) See "Drill-Bit F&D and Reserve Replacement Ratios" below for calculations.

Production volumes for the quarter ended December 31, 2016 averaged 35,793 Boe/d or a total of 3,293 MBoe, an increase of 48% over prior year's fourth quarter of 24,250 Boe/d.  Production for the fourth quarter of 2016 was comprised of 71% crude oil, 12% natural gas and 17% NGLs.  RSP's average realized commodity price per barrel of oil equivalent for the fourth quarter of 2016, before the effects of hedges, was $37.33.  RSP's average realized oil price for the fourth quarter of 2016, before the effects of hedges, was $47.23 per barrel, a negative $2.06 differential compared to average NYMEX WTI pricing of $49.29 per barrel for the same period, or 96% of NYMEX WTI pricing. RSP's average realized natural gas price for the fourth quarter of 2016, before the effects of hedges, was $2.24 per Mcf, a negative $0.74 differential compared to average NYMEX Henry Hub pricing of $2.98 per MMBtu for the same period, or 75% of NYMEX Henry Hub pricing.  RSP's average realized NGL price for the fourth quarter of 2016, before the effects of hedges, was $12.94 per Bbl, or 26% of NYMEX WTI pricing for the same time period.  Per unit cash operating expenses excluding interest expense but including lease operating expense, gathering and transportation expense, production and ad valorem taxes and recurring cash general and administrative expenses were $9.11 per Boe, an 9% decrease from prior year's comparable quarter.

Production volumes for the year ended December 31, 2016 averaged 29,161 Boe/d or a total of 10,673 MBoe, an increase of 39% over prior year's total of 21,047 Boe/d.  Production for 2016 was comprised of 73% crude oil, 11% natural gas and 16% NGLs.  RSP's average realized commodity price per barrel of oil equivalent for 2016, before the effects of hedges, was $33.15.  RSP's average realized oil price for 2016, before the effects of hedges, was $41.28 per barrel, a negative $2.04 differential compared to average NYMEX WTI pricing of $43.32 per barrel for the same period, or 95% of NYMEX WTI pricing. RSP's average realized natural gas price for 2016, before the effects of hedges, was $1.94 per Mcf, a negative $0.52 differential compared to average NYMEX Henry Hub pricing of $2.46 per MMBtu for the same period, or 79% of NYMEX Henry Hub pricing.  RSP's average realized NGL price for 2016, before the effects of hedges, was $10.87 per Bbl, or 25% of NYMEX WTI pricing for the same time period.  Per unit cash operating expenses excluding interest expense but including lease operating expense, gathering and transportation expense, production and ad valorem taxes and recurring cash general and administrative expenses were $9.54 per Boe, a 19% decrease from prior year's comparable total.

Operational Update

The Company operated three horizontal rigs in the Midland Basin during the fourth quarter, and upon closing the acquisition of SHEP I, operated one rig in the Delaware Basin during December.  RSP utilized one full-time completion crew during the fourth quarter in the Midland Basin and a part-time crew in the Delaware Basin during December.  RSP drilled 13 operated horizontal wells and completed 14 operated horizontal wells (seven Lower Spraberry, three Wolfcamp A, three Wolfcamp B and one Avalon) and two operated vertical wells during the fourth quarter.  The Company began the quarter with 12 operated horizontal drilled but uncompleted wells ("DUCs") and exited the quarter with a total of 11 operated horizontal DUCs.  During 2016, RSP drilled 46 and completed 53 operated horizontal wells (one Middle Spraberry, 35 Lower Spraberry, eight Wolfcamp A, eight Wolfcamp B and one Avalon) and drilled four and completed six operated vertical wells.

 

For the quarter ended December 31, 2016, total revenues, excluding the revenue impact from realized derivative instruments, were $122.9 million, a 67% increase over the prior year quarter of $73.5 million.  Adjusted total revenues, including the net cash from derivative instruments, were $120.5 million, an increase of 25% over the prior year quarter of $96.6 million.  Net income for the fourth quarter of 2016 was $1.4 million, or approximately one cent per diluted share, while net loss for the fourth quarter of 2015 was $20.8 million, or negative $0.21 per diluted share.  Adjusted net income for the quarter was $13.4 million, or $0.10 per diluted share, compared with adjusted net income for the prior year quarter of $12.1 million or $0.12 per diluted share.  Adjusted EBITDAX for the quarter ended was $90.5 million, an increase of 22% over the prior year quarter of $74.4 million. 

For the year ended December 31, 2016, total revenues, excluding the revenue impact from realized derivative instruments, were $353.9 million, a 25% increase over the prior year of $284.0 million.  Adjusted total revenues, including the net cash from derivative instruments, were $352.1 million, an decrease of 6% from the prior year of $376.1 million.  Net loss for the year ended 2016 was $24.9 million, or negative $0.23 per diluted share, while net loss for the year ended 2015 was $18.3 million, or negative 0.21 per diluted share.  Adjusted net loss for the year ended 2016 was  $7.4 million, or negative $0.07 per diluted share, compared with adjusted net income for the prior year of $48.6 million or $0.56 per diluted share.  Adjusted EBITDAX for the year ended 2016 was $250.3 million, a decrease of 12% from the prior year ended 2015 of $285.1 million. 

Proved Reserves Summary

RSP's proved reserves summary as of December 31, 2016 and pro forma proved reserved summary as of December 31, 2016 were prepared by Netherland, Sewell & Associates, Inc.

Our December 31, 2016 proved reserves summary included reserves from the SHEP I acquisition that closed on November 28, 2016 and totaled 236.9 MMBoe.  Pro forma for the SHEP II acquisition, which is expected to close on March 1, 2017, our total proved reserves as of December 31, 2016 were 283.3 MMBoe. The Company removed its remaining economic reserves associated with vertical proved undeveloped locations from its proved reserve base due to the superior economics of horizontal drilling locations which are expected to be drilled in front of the vertical locations over the next five years.  This resulted in a 23.4 MMBoe downward revision to proved reserves offset by positive revisions from horizontal wells that are performing above previous estimates, resulting in total downward revisions of previous estimates of 17.8 MMBoe.

The following table presents the Company's estimated net proved oil and natural gas reserves as of December 31, 2016 (excluding SHEP II acquisition) and net proved oil and natural gas reserves as of December 31, 2015, and in each case, prepared in accordance with the rules and regulations of the SEC.

The following table presents the Company's estimated net proved oil and natural gas reserves as of December 31, 2016, 2015 and 2014, as well as our pro forma net proved oil and natural gas reserves as of December 31, 2016, after giving effect to the SHEP II acquisition as if it had occurred before December 31, 2016.

Capital Expenditures

RSP's development capital expenditures, which includes our investment in drilling and completing wells, infrastructure, capitalized workovers, and other, but excludes acquisitions, for the year ended December 31, 2016 totaled $294 million ($275 million of drilling and completion and $19 million of infrastructure and other).  The Company spent approximately $57 million, or 19% of development capital, on non-operated properties.  Additionally, during 2016 the Company closed approximately $69 million of acquisitions and additions to leasehold in the Midland Basin and closed the SHEP I acquisition for approximately 15 million shares of RSP stock and $604 million in cash.

Capital Markets Transactions and Amended and Restated Credit Agreement

On October 13, 2016, the Company priced an underwritten public offering of 25.3 million shares of RSP common stock, including the exercise of the underwriters' option to purchase additional shares, raising approximately $1.0 billion in net proceeds.  On December 12, 2016, RSP priced $450 million aggregate principal amount of 5.25% senior unsecured notes due 2025 at par.  RSP used a portion of the net proceeds raised in these offerings to fund the cash portion of the SHEP I acquisition and will use the balance of the proceeds to fund the cash portion of the SHEP II acquisition.

On December 20, 2016, RSP announced it entered into an amended and restated credit agreement with respect to the Company's senior secured revolving credit facility. The amended and restated credit agreement extended the maturity date of the facility until December 19, 2021, increased the borrowing base under the facility to $950 million and increased the maximum commitments of the lenders from $1.0 billion to $2.5 billion. The $950 million borrowing base only reflected the reserve growth from the Company's Midland Basin assets and the previously closed SHEP I acquisition. Upon closing the SHEP II acquisition, RSP's borrowing base will automatically increase to $1.1 billion. RSP elected an aggregate commitment amount of $900 million under the facility and will leave this amount unchanged upon the closing of SHEP II.

As of December 31, 2016, the Company had no borrowings outstanding on its revolving credit facility and had $691 million of cash on hand.  Pro forma for closing the acquisition of SHEP II, as of December 31, 2016, the Company had $109 million of cash and no borrowings outstanding on its revolving credit facility, which has a $1.1 billion borrowing base and a $900 million Company elected commitment.

Hedging

The summary below includes all hedges in place for the full year 2017 and 2018, as of February 27, 2017.

 

2017 Annual Guidance

RSP's operating plan is expected to build momentum in the back half of 2017.  After growing production an estimated 82% - 95% in 2017, both organically and with the production volumes associated with the Silver Hill acquisition, the Company anticipates it will deliver annual production growth in excess of 30% in both 2018 and 2019 while being cash flow neutral beginning in 2018 at a $55 oil price.

As a result of the staggered closing of the Silver Hill transactions and the anticipated rig additions during the year, the investment of capital expenditures is expected to be approximately 60 - 70% in the Midland Basin and 30 - 40% in the Delaware Basin for a total developmental capital budget of $625 million to $700 million.

The Company recently deployed a fourth operated rig on its Midland Basin properties earlier than anticipated in mid-January and plans to operate at least four rigs on its Midland assets for the balance of the year.  RSP is currently operating one rig on its Delaware properties and will have a second operated rig working upon closing SHEP II.  RSP anticipates adding a third operated rig on its Delaware properties after enhancing infrastructure to enable more efficient horizontal development.  Additionally, RSP anticipates adding an additional operated rig during the fourth quarter and at that time will have a total of eight operated rigs.

The following table summarizes the Company's guidance for 2017.

Conference Call

RSP will host a conference call for investors at 1:00 PM Central Time on Tuesday, February 28, 2017, to discuss fourth quarter and full-year 2016 results.  Hosting the call will be Steve Gray, Chief Executive Officer, Zane Arrott, Chief Operating Officer and Scott McNeill, Chief Financial Officer.

The call may be accessed live over the telephone by dialing (877) 705-6003, or for international callers, (201) 493-6725.  A replay will be available shortly after the call and can be accessed by dialing (844) 512-2921, or for international callers (412) 317-6671. The passcode for the replay is 13654848.  The replay will be available until March 14, 2017. Interested parties may also listen to a simultaneous webcast of the conference call by logging onto RSP's website at www.rsppermian.com in the Investor Relations section. A replay of the webcast will also be available following the call.

About RSP Permian, Inc.

RSP is an independent oil and natural gas company focused on the acquisition, exploration, development and production of unconventional oil and associated liquids-rich natural gas reserves in the Permian Basin of West Texas. The vast majority of our acreage is located on large, contiguous acreage blocks in the core of the Midland and Delaware Basins, sub-basins of the Permian Basin. The Company's common stock is traded on the NYSE under the ticker symbol "RSPP." For more information, visit www.rsppermian.com.

Forward-Looking Statements

This news release contains forward-looking statements within the meaning of the federal securities laws. All statements, other than historical facts, that address activities that RSP assumes, plans, expects, believes, intends or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. Forward-looking statements are based on management's current beliefs, based on currently available information, as to the outcome and timing of future events. These forward-looking statements involve certain risks and uncertainties that could cause the results to differ materially from those expected by the management of RSP. Information concerning these risks and other factors can be found in RSP's filings with the SEC, including its Annual Reports on Form 10-K and Quarterly Reports on Form 10-Q, which can be obtained free of charge on the SEC's web site located at http://www.sec.gov. RSP undertakes no obligation to update or revise any forward-looking statement.

 

 

Use of Non-GAAP Financial Measures

We define Adjusted EBITDAX as oil and gas revenues including net cash receipts (payments) on settled derivative instruments and premiums paid on put options that settled during the period, less lease operating expenses, production and ad valorem taxes, and general and administrative expenses excluding stock based compensation.  Adjusted Net Income deducts from Adjusted EBITDAX depreciation, depletion, and amortization, accretion on asset retirement obligations, exploration expenses, interest expense, stock-based compensation, acquisition costs and adjusted income tax expense.

Management believes Adjusted EBITDAX and Adjusted Net Income are useful because they allow us to more effectively evaluate our operating performance and compare the results of our operations from period to period without regard to our financing methods or capital structure. We exclude the items listed above in arriving at Adjusted EBITDAX and Adjusted Net Income because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDAX and Adjusted Net Income should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of our operating performance or liquidity. Certain items excluded from Adjusted EBITDAX and Adjusted Net Income are significant components in understanding and assessing a company's financial performance, such as a company's cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDAX. Our computations of Adjusted EBITDAX and Adjusted Net Income may not be comparable to other similarly titled measures of other companies.

The following tables include a reconciliation of the non-GAAP financial measures of Adjusted EBITDAX and Adjusted Net Income to the GAAP financial measure of net income.

 

 

 

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SOURCE RSP Permian, Inc.