Antero Resources Reports Fourth Quarter and Full Year 2019 Results and Announces 2020 Guidance and Proved Reserves

DENVER, Feb. 12, 2020 /PRNewswire/ -- Antero Resources Corporation (NYSE: AR) ("Antero Resources" or the "Company") today announced its fourth quarter and full year 2019 financial and operational results as well as its 2020 capital budget, guidance and proved reserves as of December 31, 2019.  The relevant consolidated financial statements are included in Antero Resource's Annual Report on Form 10-K for the year ended December 31, 2019.

Fourth Quarter and Full Year 2019 Highlights Include:

• Net production averaged 3,185 MMcfe/d (30% liquids by volume) during the fourth quarter and 3,220 MMcfe/d for the full year, a 19% year-over-year increase compared to 2018
• Realized natural gas equivalent price averaged $3.18 per Mcfe during the quarter
• Includes pre-hedge C3+ NGL price of $29.61/Bbl
• All-in cash expenses were $2.34 per Mcfe during the quarter, a $0.22, or 8% reduction from the first half of 2019
• Net marketing expense was $0.17 per Mcfe during the quarter, a $0.05 or 23% decrease from the prior quarter
• Drilling and completion capital spending was $300 million during the fourth quarter and $1.27 billion for the full year, an 11% and 14% decrease, respectively, compared to the prior year periods
• Proved reserves increased 5% to 18.9 Tcfe at year-end 2019 compared to year-end 2018 and proved developed reserves increased 13% to 11.7 Tcfe
• Future development cost estimate for 7.2 Tcfe of proved undeveloped reserves is $0.37 per Mcfe

2020 Guidance Highlights:                                                                                                

• Drilling and completion capital budget of $1.15 billion, down 10% from 2019
• Full year 2020 net production is expected to average 3,500 MMcfe/d, a 9% increase over 2019 net production
• Liquids production, including oil, C3+ NGLs, and ethane assuming 25% recovery, is expected to average 187,500 Bbl/d
• All-in cash expenses, including net marketing expense, are expected to be $2.25 to $2.35 per Mcfe, an $0.18 decrease from 2019
• Net marketing expense is forecast to be $0.10 to $0.12 per Mcfe, an $0.11 decline from 2019
• Natural gas production guidance is 94% hedged at $2.87/MMBtu
• Estimated oil and oil-equivalent production of 26,000 Bbl/d (pentanes are hedged to WTI) is 100% hedged in 2020 at $55.63/Bbl

Paul Rady, Chairman and Chief Executive Officer of Antero Resources commented, "Our 2020 capital budget highlights the direct benefit from our well cost savings initiatives that we launched in 2019.  In simple terms, we have reduced our total well cost per foot from $970 in the initial 2019 budget to a target of $795 to $825 per for 2020.  The result is a 10% reduction in drilling and completion capital and a 28% reduction in lease operating expense as compared to 2019, while delivering production growth of 9%.  This level of production in turn should trigger $75 million in previously announced gathering, processing and transportation expense savings in 2020 and paves the way for up to $350 million in total savings between 2020 and 2023.  Additionally, by growing into our unutilized firm transportation commitments we reduce our cost structure by another $200 million by 2022."

Mr. Rady continued, "We believe that our industry-leading hedge portfolio and diversified production mix, combined with our ability to export more than 50% of our C3+ NGL production to premium international markets, provides Antero with a competitive advantage throughout commodity price cycles.  Our cost savings initiatives and liquids exposure result in a projected cash flow neutral profile for 2020 at current strip pricing including the $125 million water earnout payment received in January from Antero Midstream."

2020 Capital Budget and Guidance

The following is a summary of Antero Resources' 2020 capital budget.  The capital budget is based on commodity strip pricing as of February 7, 2020 that was $52 per barrel WTI oil, $25 per barrel C3+ NGL and $2.08 per MMBtu NYMEX natural gas for 2020. 

The following is a summary of Antero Resources' 2020 production, pricing and cash expense guidance.

Well Cost Savings

Antero's drilling and completion capital budget is based on average total well cost of $825 per foot, which is at the high end of the 2020 target range of $795 to $825 per foot.  Well costs averaged $860 per foot in the fourth quarter of 2019 with only a portion of the wells being completed with reduced water.  The reduction in 2020 well costs is expected to be driven by both drier completions (36 Bbl of water per foot of lateral) on all wells and expanded produced water services provided by Antero Midstream. 

Fourth Quarter 2019 Financial Results

For the three months ended December 31, 2019, Antero reported a GAAP net loss of $482 million, or $1.61 per diluted share, compared to a GAAP net loss of $122 million, or $0.39 per diluted share, in the prior year period.  Adjusted Net Loss (non-GAAP measure) was $6 million, or $0.02 per diluted share, compared to Adjusted Net Income of $175 million during the three months ended December 31, 2018, or $0.56 per diluted share.  The Adjusted Net Loss reflects a $468 million impairment based on the fair value of our equity interest in Antero Midstream at year end 2019.

Adjusted EBITDAX (non-GAAP measure) was $295 million, a 38% decrease compared to $475 million in the prior year period due to lower commodity pricing.  Antero's average realized price after hedges declined 20% from $3.97 per Mcfe in the fourth quarter of 2018 to $3.18 per Mcfe in the fourth quarter of 2019.

The following table details the components of average net production and average realized prices for the three months ended December 31, 2019:

Net daily natural gas equivalent production in the fourth quarter averaged 3,185 MMcfe/d, including 160,183 Bbl/d of liquids (30% liquids by volume).  Liquids revenue represented approximately 41% of total product revenue before hedges.  Production declined 1% from the prior year period due to the timing of well completions in 2019 as two pads, totaling 13 wells, were turned to sales in late December of 2019. 

Antero's average realized C3+ NGL price before hedging was $29.61 per barrel, representing a 4% decrease versus the prior year period and a 31% increase from the third quarter of 2019.  Antero shipped 41% of its total C3+ NGL net production on Mariner East 2 for export and realized a $0.21 per gallon premium to Mont Belvieu pricing on these volumes at Marcus Hook, PA.  Antero sold the remaining 59% of C3+ NGL net production at a $0.09 per gallon discount to Mont Belvieu pricing at Hopedale, OH.  The resulting blended price on 104,376 Bbl/d of net C3+ NGL production was $29.61 per barrel, which was a $0.03 per gallon premium to Mont Belvieu pricing.  Based on current strip prices at Mont Belvieu and in the international markets, Antero expects its realized C3+ NGL prices in 2020 to be $0.00 to a $0.05 per gallon premium to Mont Belvieu.  Antero expects to sell at least 50% of its C3+ NGL production in 2020 at Marcus Hook for export at a premium to Mont Belvieu.    

Cash Expense and Net Marketing Expense

All-in per unit cash expense, which includes lease operating, GP&T, production and ad valorem taxes, net marketing and general and administrative expense (excluding equity-based compensation) was $2.34 per Mcfe in the fourth quarter, an 8% decrease compared to $2.56 per Mcfe average during the first half of 2019.  Antero expects all-in cash expense of $2.25 to $2.35 per Mcfe as a result of the recently announced midstream fee reductions, filling unutilized firm transportation, and ongoing progress on the water savings initiatives that reduces lease operating expense.  

Per unit net marketing expense declined to $0.17 per Mcfe in the fourth quarter compared to $0.22 per Mcfe reported in the prior year period.  The decline was driven by the mitigation of some of our excess firm transportation expense.  Net marketing expense is expected to decline further in 2020, to $0.10 to $0.12 per Mcfe, as a result of both an increase in natural gas production filling excess firm transportation capacity and renegotiated agreements with midstream providers that allow for higher utilization of our transportation capacity to the more attractive pricing in the Gulf Coast markets. 

Adjusted EBITDAX margin (non-GAAP measure) was $1.01 per Mcfe, a 37% decrease from the prior year period, due to lower realized prices relative to the prior year period.  The following table presents a calculation of Adjusted EBITDAX margin on a per Mcfe basis and a reconciliation to the realized price before cash receipts for settled derivatives, the nearest GAAP financial measure.  Adjusted EBITDAX margin represents Adjusted EBITDAX divided by production, and is a measure that helps investors to more meaningfully evaluate and compare the results of Antero's operations on a per unit basis from period to period by removing the effect of its capital structure from its operating structure.

Fourth Quarter 2019 Operating Update

Marcellus Shale — Antero placed 21 horizontal Marcellus wells to sales during the fourth quarter of 2019 with an average lateral length of 11,600 feet.  For new wells that had 60 days of reported production data during the quarter, the average 60-day rate per well was 18.2 MMcfe/d on choke. The 60-day average rate per well included 742 Bbl/d of liquids, comprised of oil, C3+ NGLs and assumes 25% ethane recovery. 

Additionally, Antero drilled an average of 7,000 lateral feet per day in the quarter, achieving its highest quarterly rate in the Company's history.  This drilling record represents a 17% sequential increase and a 38% increase compared to the 2018 average in lateral footage performance.  Antero also drilled a company one-well record of 10,453 lateral feet in a 24-hour period.  During 2019, Antero drilled 97 wells that averaged over one mile per day drilling in the lateral and was the only known operator in the Marcellus to drill over 10,000 lateral feet in a 24-hour period, which Antero accomplished twice.  Antero's ongoing emphasis on completion efficiencies resulted in an improvement during the fourth quarter, as the Company averaged 6.3 stages completed per day, representing a 7% increase from 5.9 stages per day in the prior period.    

Fourth Quarter and Full Year 2019 Capital Investment

Antero's accrued drilling and completion capital expenditures for the three months ended December 31, 2019 were $300 million.  For the full year 2019, drilling and completion capital expenditures were $1.27 billion, a decrease of 16% from 2018 and 7% below Antero's original 2019 guidance. 

Balance Sheet and Liquidity

As of December 31, 2019, Antero's total debt was $3.76 billion, of which $552 million were borrowings outstanding under the Company's revolving credit facility.  Antero has a borrowing base of $4.5 billion with lender commitments that total $2.64 billion.  After deducting letters of credit outstanding of $623 million, the Company had $1.5 billion in available liquidity.  The decrease in Antero's outstanding letters of credit from the prior period reflect new surety bonds that were secured during the fourth quarter.  As of December 31, 2019, Antero's net debt to trailing twelve months Adjusted EBITDAX ratio was 3.0x.

Antero repurchased $225 million principal amount of senior unsecured notes during the fourth quarter at a 17% weighted average discount price, including both its 2021 and 2022 senior notes.  The repurchases reduced Antero's total debt by $37 million and net interest expense was reduced by $6 million on an annualized basis. Antero also repurchased 8.3 million shares of common stock during the fourth quarter at a weighted average price of $2.50 per share. 

President and CFO, Glen Warren, commented, "Our ability to materially reduce operating costs and lower capital spending allows us to protect our balance sheet while executing a moderate near-term growth strategy to fill our remaining unfilled premium firm transportation and realize the midstream fee reductions announced in December.  Pro forma for the recently announced asset sale program, we are targeting a mid 2-times leverage ratio with robust liquidity of $2.3 billion at year-end 2020 excluding further senior note repurchases or redemptions.  Longer term, we are committed to reducing absolute debt and maximizing free cash flow as we expect to fill our premium firm transportation commitments by the end of 2021."    

Year End Proved Reserves

At December 31, 2019, Antero's estimated proved reserves were 18.9 Tcfe, a 5% increase over the prior year.  Estimated proved reserves were comprised of 61% natural gas, 38% NGLs and 1% oil.  The Marcellus Shale accounted for 92% of estimated proved reserves and the Ohio Utica Shale accounted for 8%.  For 2019, Antero added 3.7 Tcfe of estimated proved reserves.  Approximately 2.3 Tcfe was removed from Antero's proved reserves due to the SEC 5-year rule, primarily related to changes in drilling locations in our 5-year development plan.

Estimated proved developed reserves were 11.7 Tcfe, a 13% increase over the prior year.  The percentage of estimated proved reserves classified as proved developed increased to 62% at year-end 2019, compared to 58% at year-end 2018.  Antero's 328 proved undeveloped locations average an estimated 1258 BTU, with an average lateral length of approximately 12,500 feet.

Antero's 7.2 Tcfe of estimated proved undeveloped reserves will require an estimated $2.6 billion of future development capital over the next five years, resulting in an estimated average future development cost for proved undeveloped reserves of $0.37 per Mcfe. 

The following table presents a summary of changes in estimated proved reserves (in Tcfe).

The following table summarizes pre-tax estimated proved reserves PV-10 (non-GAAP measure) and the associated Standardized Measure.  The decrease in pre-tax estimated proved reserves PV-10 value as compared to 2018, was due primarily to lower SEC pricing and the deconsolidation of Antero Resources' and Antero Midstream's financial statements.  Lower pricing resulted in approximately 65% of the decline and the deconsolidation resulted in approximately 35% of the reduction.  The deconsolidation resulted in Antero Resources recording the full fees paid to Antero Midstream for services rendered and no longer recording the future capital expenditures associated with Antero Midstream assets in future development costs. Prior to deconsolidation, as required by SEC guidance, Antero Resources' consolidated reserves included the elimination of full fees paid by Antero Resources to Antero Midstream and the inclusion of the operating costs and capital incurred by Antero Midstream.  Detailed SEC pricing can be found in Antero's Form 10-K for the year ended December 31, 2019.

Commodity Derivative Positions

Antero has hedged 1.8 Tcf of natural gas at a weighted average index price of $2.84 per MMBtu through 2023 with fixed price swap positions.  Antero also has oil and NGL fixed price swap positions, including NGL positions that totaled 35,800 Bbl/day and oil positions that totaled 10,000 Bbl/d during 2020.  As of December 31, 2019, the Company's estimated fair value of commodity derivative instruments was $1.1 billion based on strip pricing.

Please see Antero's Annual Report on Form 10-K for the year ended December 31, 2019, for more information on all commodity derivative positions. 

The following tables summarize Antero's hedge position as of December 31, 2019:

Fixed price natural gas positions from January 1, 2020 through December 31, 2023 were as follows:

C3+ NGL and Oil derivative contract positions from January 1, 2020 through December 31, 2020 were as follows:

Conference Call

A conference call is scheduled on Thursday, February 13, 2020 at 9:00 am MT to discuss the financial and operational results.  A brief Q&A session for security analysts will immediately follow the discussion of the results for the quarter.  To participate in the call, dial in at 877-407-9079 (U.S.), or 201-493-6746 (International) and reference "Antero Resources".  A telephone replay of the call will be available until Thursday, February 20, 2020 at 9:00 am MT at 877-660-6853 (U.S.) or 201-612-7415 (International) using the conference ID: 13693463.

A simultaneous webcast of the call may be accessed over the internet at www.anteroresources.com.  The webcast will be archived for replay on the Company's website until Thursday, February 20, 2020 at 9:00 am MT.

Presentation

An updated presentation will be posted to the Company's website before the conference call. The presentation can be found at www.anteroresources.com on the homepage. Information on the Company's website does not constitute a portion of, and is not incorporated by reference into, this press release.

Basis of Financial Presentation

In connection with the closing of the simplification transaction between Antero Midstream GP LP and Antero Midstream Partners LP ("Antero Midstream Partners") on March 12, 2019, among other things, Antero Midstream GP LP converted to a Delaware corporation and changed its name to Antero Midstream Corporation ("Antero Midstream") and Antero Midstream Partners became Antero Midstream's wholly owned subsidiary.  As of December 31, 2019, Antero Resources owned 29% of the shares of common stock of Antero Midstream.  Through March 12, 2019, Antero Midstream Partners' results were consolidated within Antero Resources' results.  Upon closing, Antero Midstream Partners was deconsolidated from Antero Resources and Antero Resources' interests in Antero Midstream were accounted for under the equity method of accounting within Antero Resources' results.  The GAAP results discussed below include the results of Antero Midstream Partners from January 1, 2019, through March 12, 2019, on a consolidated basis, and from March 13, 2019, to December 31, 2019, the results of Antero Midstream Partners are no longer consolidated. The non-GAAP results described herein reflect the applicable results as if the simplification transaction had occurred at the beginning of the applicable period, unless otherwise noted.

Non-GAAP Financial Measures

Adjusted Net Income (Loss) 

Adjusted Net Income (Loss) as set forth in this release represents net income (Loss), adjusted for certain items.  Antero believes that Adjusted Net Income (Loss) and Adjusted Net Income (Loss) per share is useful to investors in evaluating operational trends of the Company and its performance relative to other oil and gas producing companies.  Adjusted Net Income (Loss) is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for net income (Loss) as an indicator of financial performance.  The following tables reconcile net income (loss) before income taxes to Adjusted Net Income (Loss) (in thousands):

Per Share Amounts

Net Debt

Net Debt is calculated as total debt less cash and cash equivalents.  Management uses Net Debt to evaluate the Company's financial position, including its ability to service its debt obligations.

The following table reconciles consolidated total debt to Net Debt as used in this release (in thousands):

Adjusted EBITDAX

Adjusted EBITDAX as defined by the Company represents income or loss, including noncontrolling interests, before interest expense, interest income, gains or losses from commodity derivatives and marketing derivatives, but including net cash receipts or payments on derivative instruments included in derivative gains or losses other than proceeds from derivative monetizations, income taxes, impairment, depletion, depreciation, amortization, and accretion, exploration expense, equity-based compensation, gain or loss on early extinguishment of debt, gain or loss on sale of assets, gain or loss on changes in the fair value of contingent acquisition consideration, contract termination and rig stacking costs, distributions from unconsolidated affiliates and equity in earnings or loss of Antero Midstream. Adjusted EBITDAX also includes distributions received from limited partner interests in Antero Midstream common units prior to the closing of the simplification transaction on March 12, 2019.

The GAAP financial measure nearest to Adjusted EBITDAX is net income or loss including noncontrolling interest that will be reported in Antero's condensed consolidated financial statements.  While there are limitations associated with the use of Adjusted EBITDAX described below, management believes that this measure is useful to an investor in evaluating the Company's financial performance because it:

• is widely used by investors in the oil and gas industry to measure a company's operating performance without regard to items excluded from the calculation of such term, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired, among other factors;
• helps investors to more meaningfully evaluate and compare the results of Antero's operations from period to period by removing the effect of its capital structure from its operating structure; and
• is used by management for various purposes, including as a measure of Antero's operating performance, in presentations to the Company's board of directors, and as a basis for strategic planning and forecasting. Adjusted EBITDAX is also used by the board of directors as a performance measure in determining executive compensation.

There are significant limitations to using Adjusted EBITDAX as a measure of performance, including the inability to analyze the effect of certain recurring and non-recurring items that materially affect the Company's net income, the lack of comparability of results of operations of different companies and the different methods of calculating Adjusted EBITDAX reported by different companies.  In addition, Adjusted EBITDAX provides no information regarding a company's capital structure, borrowings, interest costs, capital expenditures, and working capital movement or tax position.

The following table represents a reconciliation of Adjusted EBITDAX to net income (loss), including noncontrolling interest to Adjusted EBITDAX for the periods presented.  Adjusted EBITDAX also excludes the results of Antero Midstream in order to provide comparability with the current structure of Antero Resources as Antero Resources no longer consolidates Antero Midstream's results, effective March 13, 2019.  These Adjustments are disclosed in the table below as Antero Midstream related adjustments.

The following table reconciles Antero's net income to Adjusted EBITDAX for the twelve months ended December 31, 2019, as used in this release (in thousands):

Drilling and Completion Capital Expenditures

For a reconciliation between cash paid for drilling and completion capital expenditures and drilling and completion accrued capital expenditures during the period, please see the capital expenditures section below. (in thousands):

F&D Cost & Pre-Tax PV-10 Value

The pre-tax PV-10 value is a non-GAAP financial measure.  Antero believes that the presentation of pre-tax PV-10 is useful to its investors because it presents the discounted future net cash flows attributable to reserves prior to taking into account corporate future income taxes and the Company's current tax structure.  The Company further believes investors and creditors use pre-tax PV-10 values as a basis for comparison of the relative size and value of its reserves as compared with other companies.       

The GAAP financial measure most directly comparable to pre-tax PV-10 is the standardized measure of discounted future net cash flows ("Standardized Measure").  To reconcile to Standardized Measure to pre-tax PV-10, the Company reduces Standardized Measure by the discounted future income taxes associated with the Company's proved reserves. The following sets forth the estimated future net cash flows from our proved reserves (without giving effect to our commodity derivatives), the present value of those net cash flows before income tax (PV-10) and the present value of those net cash flows after income tax (Standardized measure) at December 31, 2019.

Notwithstanding their use for comparative purposes, the Company's non-GAAP financial measures may not be comparable to similarly titled measures employed by other companies.

Antero Resources is an independent natural gas and oil company engaged in the acquisition, development and production of unconventional liquids-rich natural gas properties located in the Appalachian Basin in West Virginia and Ohio. The Company's website is located at www.anteroresources.com.  

This release includes "forward-looking statements." Such forward-looking statements are subject to a number of risks and uncertainties, many of which are not under Antero Resources' control. All statements, except for statements of historical fact, made in this release regarding activities, events or developments Antero Resources expects, believes or anticipates will or may occur in the future, such as those regarding expected results, future commodity prices, future production targets, realizing potential future fee rebates or reductions, including those related to certain levels of production, future earnings, leverage targets and debt repayment, future capital spending plans, asset monetization opportunities and pricing, improved and/or increasing capital efficiency, estimated realized natural gas, NGL and oil prices, expected drilling and development plans, projected well costs and cost savings initiatives, future financial position, the amount and timing of any litigation settlements, and future marketing opportunities are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All forward-looking statements speak only as of the date of this release. Although Antero Resources believes that the plans, intentions and expectations reflected in or suggested by the forward-looking statements are reasonable, there is no assurance that these plans, intentions or expectations will be achieved. Therefore, actual outcomes and results could materially differ from what is expressed, implied or forecast in such statements. Except as required by law, Antero Resources expressly disclaims any obligation to and does not intend to publicly update or revise any forward-looking statements.

Antero Resources cautions you that these forward-looking statements are subject to all of the risks and uncertainties, incident to the exploration for and development, production, gathering and sale of natural gas, NGLs and oil most of which are difficult to predict and many of which are beyond the Antero Resources' control. These risks include, but are not limited to, commodity price volatility, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating natural gas and oil reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, and the other risks described under the heading "Item 1A. Risk Factors" in Antero Resources' Annual Report on Form 10-K for the year ended December 31, 2019.

SOURCE Antero Resources Corporation