AR Antero Resources Corporation

DENVER, July 26, 2023 /PRNewswire/ -- Antero Resources Corporation (NYSE: AR) ("Antero Resources," "Antero," or the "Company") today announced its second quarter 2023 financial and operating results. The relevant consolidated financial statements are included in Antero Resources' Quarterly Report on Form 10-Q for the quarter ended June 30, 2023. 

Second Quarter 2023 Highlights:

• Net production averaged 3.4 Bcfe/d
• • Liquids production averaged 192 MBbl/d, an increase of 16% from the year ago period
  • Natural gas production averaged 2.2 Bcf/d, flat from the year ago period
• Realized a pre-hedge natural gas equivalent price of $2.89 per Mcfe, a $0.79 per Mcfe premium to NYMEX pricing
• • Realized a C3+ NGL price of $34.16 per barrel
  • Realized a pre-hedge natural gas price of $2.14 per Mcf, a $0.04 per Mcf premium to NYMEX pricing
• Net loss was $83 million, Adjusted Net Loss was $84 million (Non-GAAP)
• Adjusted EBITDAX was $113 million (Non-GAAP); net cash provided by operating activities was $155 million
• Averaged over 11 completion stages per day per completion crew during the second quarter, a 3% increase sequentially and an increase of 40% compared to the 2022 average
• Net Debt to trailing last twelve month Adjusted EBITDAX was 0.8x (Non-GAAP)

2023 Guidance Updates:

• Increasing full year 2023 production guidance by 100 MMcfe/d, or 3%, to a range of 3.35 to 3.4 Bcfe/d
• Decreasing cash production costs by $0.05 per Mcfe to a range of $2.35 to $2.45 per Mcfe
• Decreasing realized natural gas price premium to NYMEX Henry Hub by $0.05 per Mcf to $0.00 to $0.10 per Mcf

Paul Rady, Chairman, CEO and President of Antero Resources commented, "Our second quarter results continue to build on the operational momentum that we achieved in the first quarter. During the quarter, we achieved a number of new company quarterly drilling and completion records, including footage drilled in a 24-hour period and completion stages pumped per day. These operational efficiencies are expected to result in lower maintenance capital expenditures going forward. Further, the continued strength in our well performance allows us to increase our 2023 production guidance by 3%, while maintaining the same capital budget."

Mr. Rady continued, "The industry has responded to lower commodity prices through meaningful reductions in rig and completion activity. Looking ahead, we expect natural gas demand to increase on higher LNG exports and natural gas fired electric power burn, which in turn should further balance the market and support natural gas prices. We are uniquely positioned to benefit from increasing NYMEX prices with 75% of our natural gas being sold at Antero's premium delivery points in the LNG corridor."

Michael Kennedy, CFO of Antero Resources said, "Antero's improved capital efficiency is expected to result in 2024 capital requirements that are 10% below our 2023 capital guidance. This capital program will target maintaining our increased 2023 production guidance. Further, the capital efficiency gains are expected to result in positive Free Cash Flow in 2023, and when combined with a higher natural gas strip, generate substantial Free Cash Flow in 2024. As a reminder, we target returning 50% of our Free Cash Flow to our shareholders."

For a discussion of the non-GAAP financial measures including Adjusted Net Income, Adjusted EBITDAX, Free Cash Flow and Net Debt please see "Non-GAAP Financial Measures."

2023 Guidance Update 

Antero is increasing its full year 2023 production guidance to 3.35 to 3.4 Bcfe/d, an increase at the midpoint of 100 MMcfe/d, or 3%. The higher expected volumes are driven by strong well performance and capital efficiency gains, which more than offset lower ethane volumes due to the timing of the Shell ethane cracker.  

Antero is decreasing its cash production expense guidance by $0.05 per Mcfe to a range of $2.35 to $2.45 per Mcfe reflecting lower fuel costs and production tax. Antero is also decreasing its natural gas realized price guidance by $0.05 per Mcf, to a range of $0.00 to $0.10 per Mcf due to the lower natural gas strip that reduces the BTU uplift Antero realizes.

Free Cash Flow 

During the second quarter of 2023, Free Cash Flow was ($159) million.

During the first half of 2023, Free Cash Flow was $14 million.

Return of Capital Program

Antero purchased 0.7 million shares for $16 million during the second quarter of 2023. Shares purchased during the quarter were used to offset tax withholding obligations related to the vesting of equity awards to Antero employees. Since the inception of the share repurchase program in the first quarter of 2022, Antero has purchased 31.1 million shares for approximately $1 billion, or 10% of common shares outstanding. The Company currently has approximately $1 billion of remaining capacity under the announced share repurchase program.

Second Quarter 2023 Financial Results

Net daily natural gas equivalent production in the second quarter averaged 3.4 Bcfe/d, including 192 MBbl/d of liquids, an increase of 5% from the second quarter of 2022. As a result of Antero's focus on its liquids-rich Marcellus acreage, liquids volumes increased by 16%, while natural gas volumes were flat, each compared to the year ago period.

Antero's average realized natural gas price before hedging was $2.14 per Mcf, a $0.04 per Mcf premium to the average first-of-month ("FOM") NYMEX Henry Hub price.

The following table details average net production and average realized prices for the three months ended June 30, 2023:

Antero's average realized C3+ NGL price was $34.16 per barrel. Antero shipped 54% of its total C3+ NGL net production on Mariner East 2 ("ME2") for export and realized a $0.07 per gallon premium to Mont Belvieu pricing on these volumes at Marcus Hook, PA. Antero sold the remaining 46% of C3+ NGL net production at a $0.10 per gallon discount to Mont Belvieu pricing at Hopedale, OH. The resulting blended price on 112 MBbl/d of net C3+ NGL production was a $0.01 per gallon discount to Mont Belvieu pricing. 

All-in cash expense, which includes lease operating, gathering, compression, processing, and transportation, production and ad valorem taxes was $2.35 per Mcfe in the second quarter, a 10% decrease compared to $2.61 per Mcfe average during the second quarter of 2022. The decrease was due primarily to lower production tax and lower fuel costs as a result of lower commodity prices. Net marketing expense was $0.07 per Mcfe in the second quarter, a decrease from $0.09 per Mcfe during the second quarter of 2022. The decrease in net marketing expense was due to reduced firm transportation commitments between periods.

Second Quarter 2023 Operating Results

Antero placed 26 horizontal Marcellus wells to sales during the second quarter with an average lateral length of 12,800 feet. Of the wells placed to sales, 20 of these wells have been on line for at least 60 days.  The average 60-day rate per well was 26.5 MMcfe/d with approximately 1,236 Bbl/d of liquids per well assuming 25% ethane recovery. The remaining six wells were completed in early June. Pad highlights include:

• A six well pad with an average lateral length of 15,900 feet had an average 60-day rate per well of 29.0 MMcfe/d, including approximately 1,744 Bbl/d of liquids per well assuming 25% ethane recovery
• A seven well pad with an average lateral length of 12,700 feet had an average 60-day rate per well of 27.2 MMcfe/d, including approximately 1,436 Bbl/d of liquids per well assuming 25% ethane recovery

Drilling and completion activity during the second quarter of 2023 set numerous company records. These records include average stages per day for the quarter at 11.2 stages per day, average stages per day of an entire pad of 12.1 stages per day and a one-day record of 16 stages per day achieved in June. Drilling performance also improved during the quarter, averaging 6,055 lateral feet per day in the second quarter, up 8% from the first quarter 2023 average. Antero has achieved seven of its top 12 lateral feet per day records in 2023, including a high of 12,340 lateral feet per day.

Second Quarter 2023 Capital Investment

Antero's accrued drilling and completion capital expenditures for the three months ended June 30, 2023, were $247 million. Through the first half of 2023, the Company has completed 2,467 of 4,209 stages, or 59%, of its 2023 budgeted completion stages.

In addition to capital invested in drilling and completion activities, the Company invested $36 million in land during the second quarter. During the quarter, Antero added approximately 8,000 net acres, representing over 27 incremental drilling locations at an average cost of $1 million per location. Through the first half of 2023, Antero has added approximately 20,000 net acres representing over 75 incremental drilling locations at an average cost of less than $1 million per location. Antero's organic leasing efforts focus on acreage in close proximity to its current development plan. These incremental locations more than offset Antero's maintenance capital plan that requires an average of 60 to 65 wells per year. In addition, these efforts allow Antero to increase the average lateral length in its development program, which is expected to average 14,500 feet for wells drilled in 2023, or 7% longer than the 2022 average of 13,600 feet. The Company believes this organic leasing program is the most cost effective approach to lengthening its core inventory position.

Commodity Derivative Positions

Antero did not enter into any new natural gas, NGL or oil hedges during the second quarter of 2023.

Please see Antero's Quarterly Report on Form 10-Q for the quarter ended June 30, 2023, for more information on all commodity derivative positions.  For detail on current commodity positions, please see the Hedge Profile presentations at www.anteroresources.com.

Conference Call

A conference call is scheduled on Thursday, July 27, 2023 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. 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, August 3, 2023 at 9:00 am MT at 877-660-6853 (U.S.) or 201-612-7415 (International) using the conference ID: 13740094. To access the live webcast and view the related earnings conference call presentation, visit Antero's website at www.anteroresources.com.  The webcast will be archived for replay until Thursday, August 3, 2023 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.

Non-GAAP Financial Measures

Adjusted Net Income 

Adjusted Net Income as set forth in this release represents net income, adjusted for certain items. Antero believes that Adjusted Net Income 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 is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for net income as an indicator of financial performance. The GAAP measure most directly comparable to Adjusted Net Income is net income. The following table reconciles net income to Adjusted Net Income (in thousands):

Net Debt

Net Debt is calculated as total long-term 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 long-term debt to Net Debt as used in this release (in thousands):

Free Cash Flow

Free Cash Flow is a measure of financial performance not calculated under GAAP and should not be considered in isolation or as a substitute for cash flow from operating, investing, or financing activities, as an indicator of cash flow or as a measure of liquidity. The Company defines Free Cash Flow as net cash provided by operating activities, less net cash used in investing activities, which includes drilling and completion capital and leasehold capital, plus payments for early contract termination or derivative monetization, less proceeds from asset sales or derivative monetization and less distributions to non-controlling interests in Martica.

The Company has not provided projected net cash provided by operating activities or a reconciliation of Free Cash Flow to projected net cash provided by operating activities, the most comparable financial measure calculated in accordance with GAAP. The Company is unable to project net cash provided by operating activities for any future period because this metric includes the impact of changes in operating assets and liabilities related to the timing of cash receipts and disbursements that may not relate to the period in which the operating activities occurred. The Company is unable to project these timing differences with any reasonable degree of accuracy without unreasonable efforts.

Free Cash Flow is a useful indicator of the Company's ability to internally fund its activities, service or incur additional debt and estimate return of capital. There are significant limitations to using Free Cash Flow 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 Free Cash Flow reported by different companies. Free Cash Flow does not represent funds available for discretionary use because those funds may be required for debt service, land acquisitions and lease renewals, other capital expenditures, working capital, income taxes, exploration expenses, and other commitments and obligations.

Adjusted EBITDAX 

Adjusted EBITDAX is a non-GAAP financial measure that we define as net income (loss), adjusted for certain items detailed below. 

Adjusted EBITDAX as used and defined by us, may not be comparable to similarly titled measures employed by other companies and is not a measure of performance calculated in accordance with GAAP. Adjusted EBITDAX should not be considered in isolation or as a substitute for operating income or loss, net income or loss, cash flows provided by operating, investing, and financing activities, or other income or cash flow statement data prepared in accordance with GAAP. Adjusted EBITDAX provides no information regarding our capital structure, borrowings, interest costs, capital expenditures, working capital movement, or tax position. Adjusted EBITDAX does not represent funds available for discretionary use because those funds may be required for debt service, capital expenditures, working capital, income taxes, exploration expenses, and other commitments and obligations. However, our management team believes Adjusted EBITDAX is useful to an investor in evaluating our financial performance because this measure:

• is widely used by investors in the oil and natural gas industry to measure operating performance without regard to items excluded from the calculation of such term, which may vary substantially from company to company depending upon accounting methods and the 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 our operations from period to period by removing the effect of our capital and legal structure from our operating structure;
• is used by our management team for various purposes, including as a measure of our operating performance, in presentations to our Board of Directors, and as a basis for strategic planning and forecasting: and
• is used by our 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 effects of certain recurring and non-recurring items that materially affect our net income or loss, the lack of comparability of results of operations of different companies, and the different methods of calculating Adjusted EBITDAX reported by different companies.

The GAAP measures most directly comparable to Adjusted EBITDAX are net income (loss) and net cash provided by operating activities.  The following table represents a reconciliation of Antero's net income (loss), including noncontrolling interest, to Adjusted EBITDAX and a reconciliation of Antero's Adjusted EBITDAX to net cash provided by operating activities per our consolidated statements of cash flows, in each case, for the three months ended June 30, 2022 and 2023. Adjusted EBITDAX also excludes the noncontrolling interests in Martica, and these adjustments are disclosed in the table below as Martica related adjustments.

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):

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 natural gas liquids company engaged in the acquisition, development and production of unconventional properties located in the Appalachian Basin in West Virginia and Ohio. In conjunction with its affiliate, Antero Midstream (NYSE: AM), Antero is one of the most integrated natural gas producers in the U.S.  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 our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management,  return of capital, 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, 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 participation level of our drilling partner and the financial and production results to be achieved as a result of that drilling partnership, the other key assumptions underlying our projections, 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, supply chain or other disruption, lack of availability and cost of drilling, completion and production equipment and services and cost of drilling, completion and production equipment and services, environmental risks, drilling and completion and other operating risks, marketing and transportation risks, regulatory changes or changes in law, the uncertainty inherent in estimating natural gas, NGLs and oil reserves and in projecting future rates of production, cash flows and access to capital, the timing of development expenditures, conflicts of interest among our stockholders, impacts of geopolitical and world health events, cybersecurity risks, our ability to achieve our greenhouse gas reduction targets and the costs associated therewith, the state of markets for, and availability of, verified quality carbon offsets 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, 2022 and Quarterly Report on Form 10-Q for the quarter ended June 30, 2023.

The following table sets forth selected financial data for the three months ended June 30, 2022 and 2023: