Antero Resources Reports Third Quarter 2022 Results and Increases Share Repurchase Program by $1 Billion Image

Antero Resources Reports Third Quarter 2022 Results and Increases Share Repurchase Program by $1 Billion

DENVER, Oct. 26, 2022 /PRNewswire/ -- Antero Resources Corporation (NYSE: AR) ("Antero Resources," "Antero," or the "Company") today announced its third quarter 2022 financial and operating results. The relevant consolidated financial statements are included in Antero Resources' Quarterly Report on Form 10-Q for the quarter ended September 30, 2022. 

Third Quarter 2022 Highlights Include:

  • Net production averaged 3.2 Bcfe/d, including 171 MBbl/d of liquids  
  • Realized pre-hedge natural gas price of $8.69 per Mcf, a $0.49 per Mcf premium to NYMEX pricing
  • Realized C3+ NGL price of $50.61 per barrel, or 55% of WTI
  • Net income was $560 million, Adjusted Net Income was $531 million (Non-GAAP)
  • Adjusted EBITDAX was $878 million (Non-GAAP); net cash provided by operating activities was $1.1 billion
  • Free Cash Flow was $797 million (Non-GAAP)
  • Reduced total debt by $404 million during the quarter
  • Purchased $382 million of shares during the quarter
  • Net Debt at quarter end was $1.17 billion (Non-GAAP)
  • Net Debt to trailing last twelve month Adjusted EBITDAX declined to 0.4x (Non-GAAP)

Paul Rady, Chairman, Chief Executive Officer and President of Antero Resources commented, "Antero's third quarter results reflect the Company's core strengths that include access to premium priced markets through our firm transportation portfolio and low absolute debt. At a time when basis differentials are widening across the U.S., Antero's differentiated strategy delivered a $0.49 per Mcf premium to NYMEX. Through our direct sales contracts along the LNG corridor, we anticipate our premium in basis pricing relative to NYMEX Henry Hub to increase further as additional LNG facilities are placed in service. Today's balance sheet strength and a strong Free Cash Flow outlook will allow us to deliver significant capital returns to our shareholders in the quarters ahead." 

Mr. Rady continued, "We remain committed to maintaining our leadership position in ESG. Our 2021 ESG achievements highlight our continued focus on the communities where we live and operate, while keeping our workforce safe. We have made tremendous progress on our commitment to achieve Net Zero Scope 1 and 2 GHG emissions by 2025, already reducing our peer-leading GHG emissions by 36% since 2019. Our ability to provide lower carbon energy to both our communities at home and abroad, directly improves the health, safety and livelihood for people living in energy poverty."

Michael Kennedy, Chief Financial Officer of Antero Resources said, "The $1 billion increase in our share repurchase authorization highlights the confidence we have in our business strategy and the significant Free Cash Flow that it generates."

Mr. Kennedy added, "Since the start of our debt reduction program in the fourth quarter of 2019, we have reduced debt by $2.6 billion, including $400 million during the third quarter and almost $1 billion year to date. Because of this aggressive focus on debt reduction, we are now poised to return the majority 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."

 

2022 Debt Reduction and Capital Return Program

 

 

Three Months Ended
September 30, 2022

 

 

Nine Months Ended
September 30, 2022

Total shares purchased (MM) (1)

10.5

21.5

Share purchases ($MM)

$382

$740

Absolute debt reduction ($MM) 

$404

$953

Total debt reduction and capital return ($MM)

$786

$1,693

(1)

For the three and nine months ended September 30, 2022, the total number of shares purchased includes 0.03 million  and 2.9 million shares, respectively, of Antero common stock related to satisfying tax withholding obligations incurred upon the vesting of restricted stock units and performance share units held by our employees.

Debt Reduction

As of September 30, 2022, Antero's total debt was $1.17 billion. Net Debt to trailing twelve month Adjusted EBITDAX was 0.4x. During the third quarter, Antero reduced total debt by $404 million including a $62 million reduction in borrowings under the credit facility, the repurchase of $300 million aggregate principal amount of its 2026 and 2029 Senior Notes pursuant to its tender offer, the repurchase of $22 million aggregate principle amount of senior notes in the open market and the redemption of $20 million of its convertible debt.

Increased Share Repurchase Program

On October 25, 2022, Antero's Board of Directors authorized a $1 billion increase in the Company's share repurchase program to $2 billion. During the third quarter of 2022, Antero purchased 10.5 million shares at a weighted average price of $36.56 per share for $382 million. For the first nine months of 2022, Antero purchased 21.5 million shares at a weighted average price of $34.84 per share for $740 million. Combined with the new authorization, this results in $1.3 billion of remaining capacity under the share repurchase program.

Free Cash Flow

During the third quarter, Antero generated $797 million of Free Cash Flow. Free Cash Flow before Changes in Working Capital was $556 million.   

Three Months Ended
September 30,

2021

2022

Net cash provided by operating activities

$

312,680

1,087,672

Less: Net cash used in investing activities

(202,577)

(243,529)

Less: Proceeds from asset sales

(952)

Less: Distributions to non-controlling interests in Martica

(18,755)

(46,217)

Free Cash Flow

$

91,348

796,974

Changes in Working Capital

30,651

(241,136)

Free Cash Flow before Changes in Working Capital

$

121,999

555,838

 

Borrowing Base Redetermination

The borrowing base under Antero Resources' credit facility was reaffirmed at $3.5 billion in October of 2022. Lender commitments under the credit facility remained at $1.5 billion. As of September 30, 2022, Antero had $9 million drawn under its credit facility.

Guidance Update 

Antero is revising its cash production expense guidance to a range of $2.55 to $2.65 per Mcfe reflecting higher fuel costs and ad valorem tax due to the increase in commodity prices.

Antero is also increasing its drilling and completion capital expenditure guidance reflecting completion activity being pulled into the fourth quarter and incremental inflationary pressure related in part to higher services, diesel and steel costs. Development optimization to retain preferred crews is expected to result in an additional pad being completed in late December that had originally been planned for the first quarter of 2023. Antero now expects 72 wells to be completed in 2022, compared to initial guidance of 60 to 65 wells. These additional well completions are expected to lead to higher sequential production in the first quarter of 2023.

Land capital guidance is increasing to a range of $125 to $150 million due to continued success in the organic leasing program that has allowed Antero to increase its premium drilling locations in its liquids-rich fairway. During the third quarter, Antero added approximately 5,500 net acres which hold approximately 25 incremental drilling locations at an average cost of under $1 million per location. During the first nine months of 2022, Antero's organic leasing program has added approximately 60 drilling locations in the core of the Appalachia liquids area at an average cost of under $1 million per location, essentially offsetting Antero's maintenance capital plan that assumes an average of 60 to 65 wells per year. In addition to the incremental locations added, Antero also acquired minerals in its Marcellus area of development to increase its net revenue interest in future drilling locations. The Company believes this organic leasing program is the most cost efficient approach to lengthening its core inventory position.

Full Year 2022 –
Prior

Full Year 2022 –
Revised

Full Year 2022 Guidance

Low

High

Low

High

Cash Production Expense ($/Mcfe)

$2.40

$2.50

$2.55

$2.65

Drilling and Completion Capital ($MM) 

$725

$750

$775

$800

Land Capital ($MM)

$100

$110

$125

$150

Fourth Quarter 2022 Guidance

Low

High

Cash Production Expense ($/Mcfe)

$2.55

$2.65

Production (Bcfe/d) 

3.25

3.35

Note: Any 2022 projections not discussed in this release are unchanged from previously stated guidance.

 

Third Quarter 2022 Financial Results

Net daily natural gas equivalent production in the third quarter averaged 3.2 Bcfe/d, including 171 MBbl/d of liquids, as detailed in the table below. Due to the ongoing commissioning of the Shell Cracker and an NGL downstream pipeline outage at the beginning of October that required volumes to be shut in temporarily, Antero anticipates fourth quarter production volumes will be 3.25 to 3.35 Bcfe/d. Full year 2022 production guidance remains unchanged at a range of 3.2 to 3.3 Bcfe/d with expectations to now be at the low end of the range.   

Antero's average realized natural gas price before hedging was $8.69 per Mcf, representing a 102% increase compared to the prior year period. Antero realized a $0.49 per Mcf premium to the average NYMEX Henry Hub price. The realized natural gas price benefited from higher premiums to NYMEX at the price hubs where Antero sells its natural gas in the LNG fairway of the Gulf Coast. Antero sells approximately 75% of its natural gas into these premium priced NYMEX related hubs.

The following table details average net production and average realized prices for the three months ended September 30, 2022:

 

Three Months Ended September 30, 2022

Combined

Natural

Natural
Gas

Oil

C3+ NGLs

Ethane

Gas
Equivalent

(MMcf/d)

(Bbl/d)

(Bbl/d)

(Bbl/d)

(MMcfe/d)

Average Net Production

2,172

8,734

108,153

54,460

3,200

Combined

Natural

Natural
Gas

Oil

C3+ NGLs

Ethane

Gas
Equivalent

Average Realized Prices

($/Mcf)

($/Bbl)

($/Bbl)

($/Bbl)

($/Mcfe)

Average realized prices before settled derivatives

$

8.69

$

83.41

$

50.61

$

23.40

$

8.23

Average index price (1)

$

8.20

$

91.55

$

8.20

Premium / (Discount) to average index price

$

0.49

$

(8.14)

$

0.03

Settled commodity derivatives (2)

$

(3.18)

$

(0.65)

$

(0.34)

$

(2.17)

Average realized prices after settled derivatives

$

5.51

$

82.76

$

50.27

$

23.40

$

6.06

Premium / (Discount) to average index price

$

(2.69)

$

(8.79)

$

(2.14)

 

(1)

The average index prices for natural gas and oil represent the New York Mercantile Exchange average first-of-month price and the Energy Information Administration calendar month average West Texas Intermediate settled futures price, respectively.

(2)

These commodity derivative instruments include contracts attributable to Martica Holdings LLC ("Martica"), Antero's consolidated variable interest entity. All gains or losses from Martica's derivative instruments are fully attributable to the noncontrolling interests in Martica, which includes portions of the natural gas and all oil and C3+ NGL derivative instruments during the three months ended September 30, 2022.

Antero's average realized C3+ NGL price was $50.61 per barrel. Antero shipped 61% of its total C3+ NGL net production on Mariner East 2 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 39% of C3+ NGL net production at a $0.09 per gallon discount to Mont Belvieu pricing at Hopedale, OH. The resulting blended price on 108 MBbl/d of net C3+ NGL production was in line with Mont Belvieu pricing. 

Three Months Ended September 30, 2022

Pricing Point

Net C3+ NGL

Production
(Bbl/d)

% by
Destination

Premium (Discount)

To Mont Belvieu
($/Gal)

Propane / Butane exported on ME2

Marcus Hook, PA

65,833

61 %

$0.07

Remaining C3+ NGL volume

Hopedale, OH

42,320

39 %

($0.09)

Total C3+ NGLs/Blended Premium  

108,153

100 %

$0.00

 

All-in cash expense, which includes lease operating, gathering, compression, processing and transportation, production and ad valorem taxes was $2.84 per Mcfe in the third quarter, a 21% increase compared to $2.35 per Mcfe average during the third quarter of 2021. The increase was due primarily to higher natural gas and fuel costs that impacted gathering, processing and transportation costs and an increase in production taxes as a result of higher commodity prices during the quarter. Fourth quarter cash production expense is expected to decline sequentially to a range of $2.55 to $2.65 per Mcfe, driven by lower commodity prices and lower volumes being shipped on Mariner East 2.

Net marketing expense was $0.09 per Mcfe in the third quarter, a decrease from $0.11 per Mcfe during the third quarter of 2021 due to lower firm transportation commitments from the year ago period.

Third Quarter 2022 Operating Update

Antero placed 22 horizontal Marcellus wells to sales during the third quarter with an average lateral length of 13,600 feet. Ten of these wells have been on line for at least 60 days and the average 60-day rate per well was 27.4 MMcfe/d, including an Antero record of approximately 1,509 Bbl/d of liquids per well assuming 25% ethane recovery. The remaining 12 wells were completed in September and will contribute to the volume increase in the fourth quarter. 

Third Quarter 2022 Capital Investment

Antero's accrued drilling and completion capital expenditures for the three months ended September 30, 2022, were $227 million. For a reconciliation of accrued capital expenditures to cash capital expenditures, see the table in the Non-GAAP Financial Measures section.

In addition to capital invested in drilling and completion costs, the Company invested $46 million in land during the third quarter.

Commodity Derivative Positions

Antero did not enter into any new natural gas, NGL or oil hedges during the third quarter of 2022. The following table details Antero's realized hedge loss for the three months ended September 30, 2022:

Volume
(MMBtu/d)

Price
($/MMBtu)

Realized

Hedge Loss
($MM)

Fixed Price Swaps

1,106

$2.48

$582

Overriding Royalty Interest Transaction Swaps (1)

42

$2.39

$22

Volumetric Production Payment Transaction Swaps (2)

59

$2.55

$31

1,207

$635

 

Note: Excludes basis swap positions.

(1) 

Represents hedges related to the Overriding Royalty Interest transaction that was completed in the second quarter of 2020.  The hedge losses are fully
attributable to the noncontrolling interest in Martica and are netted out of the distributions attributable to the noncontrolling interest owner.

(2) 

Represents hedges related to the Volumetric Production Payment transaction that was completed in the third quarter of 2020.

Please see Antero's Quarterly Report on Form 10-Q for the quarter ended September 30, 2022, 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, October 27, 2022 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, November 3, 2022 at 9:00 am MT at 877-660-6853 (U.S.) or 201-612-7415 (International) using the conference ID: 13726232. 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, November 3, 2022 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 (loss), 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 (loss). The following table reconciles net income (loss) to Adjusted Net Income (in thousands):

Three Months Ended September 30,

2021

2022

Net income (loss) and comprehensive income (loss) attributable to Antero Resources
Corporation

$

(549,318)

559,759

Net income (loss) and comprehensive income (loss) attributable to noncontrolling interests

(17,257)

34,748

Unrealized commodity derivative (gains) losses

834,334

(109,424)

Amortization of deferred revenue, VPP

(11,404)

(9,478)

Loss (gain) on sale of assets

(539)

214

Impairment of oil and gas properties

26,253

33,924

Equity-based compensation

5,298

10,402

Loss on early extinguishment of debt

16,567

30,307

Loss on convertible note inducement

169

Equity in earnings of unconsolidated affiliate

(21,450)

(14,972)

Contract termination

3,370

17,995

Tax effect of reconciling items (1)

(205,127)

9,486

80,727

563,130

Martica adjustments (2)

(20,166)

(31,984)

Adjusted Net Income

$

60,561

531,146

Diluted Weighted Average Shares Outstanding (3)

313,790

325,997

 

(1)

Deferred taxes were 24% and 23% for 2021 and 2022, respectively.

(2)

Adjustments reflect noncontrolling interest in Martica not otherwise adjusted in amounts above.

(3)

Diluted weighted average shares outstanding does not include securities that would have had an anti-dilutive effect on the computation of diluted earnings (loss) per share.  Anti-dilutive weighted average shares outstanding for the three months ended September 30, 2021 and 2022 were 28 million and 0.3 million, respectively. 

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

December 31,

September 30,

2021

2022

Credit Facility

$

9,000

5.000% senior notes due 2025

584,635

8.375% senior notes due 2026

325,000

103,892

7.625% senior notes due 2029

584,000

415,837

5.375% senior notes due 2030

600,000

600,000

4.250% convertible senior notes due 2026

81,570

56,932

Unamortized discount, net

(27,772)

Unamortized debt issuance costs

(21,989)

(12,833)

Total long-term debt

$

2,125,444

1,172,828

Less: Cash and cash equivalents

Net Debt

$

2,125,444

1,172,828

 

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, less proceeds from asset sales 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 and years ended September 30, 2021 and 2022. Adjusted EBITDAX also excludes the noncontrolling interests in Martica, and these adjustments are disclosed in the table below as Martica related adjustments.

Three Months Ended September 30,

2021

2022

Reconciliation of net income (loss) to Adjusted EBITDAX:

Net income (loss) and comprehensive income (loss) attributable to Antero Resources
Corporation

$

(549,318)

559,759

Net income (loss) and comprehensive income (loss) attributable to noncontrolling interests

(17,257)

34,748

Unrealized commodity derivative (gains) losses

834,334

(109,424)

Amortization of deferred revenue, VPP

(11,404)

(9,478)

Loss (gain) on sale of assets

(539)

214

Interest expense, net

45,414

28,326

Loss on early extinguishment of debt

16,567

30,307

Loss on convertible note inducement

169

Income tax expense (benefit)

(158,656)

135,823

Depletion, depreciation, amortization and accretion

183,638

170,237

Impairment of oil and gas properties

26,253

33,924

Exploration expense

235

1,263

Equity-based compensation expense

5,298

10,402

Equity in earnings of unconsolidated affiliate

(21,450)

(14,972)

Dividends from unconsolidated affiliate

31,285

31,285

Contract termination, transaction expense and other

3,996

18,080

388,396

920,663

Martica related adjustments (1)

(30,197)

(42,563)

Adjusted EBITDAX

$

358,199

878,100

Reconciliation of our Adjusted EBITDAX to net cash provided by operating activities:

Adjusted EBITDAX

$

358,199

878,100

Martica related adjustments (1)

30,197

42,563

Interest expense, net

(45,414)

(28,326)

Exploration expense

(235)

(1,263)

Changes in current assets and liabilities

(28,316)

213,999

Transaction expense

(626)

Contract termination expense

(3,370)

(17,995)

Other items

2,245

594

Net cash provided by operating activities

$

312,680

1,087,672

(1)

Adjustments reflect noncontrolling interests in Martica not otherwise adjusted in amounts above. 

 

Twelve

Months Ended

September 30,

2022

Reconciliation of net income to Adjusted EBITDAX:

Net income and comprehensive income attributable to Antero Resources Corporation

$

2,069,860

Net income and comprehensive income attributable to noncontrolling interests

120,005

Unrealized commodity derivative gains

(702,965)

Amortization of deferred revenue, VPP

(39,528)

Loss on sale of assets

2,666

Interest expense, net

144,000

Loss on early extinguishment of debt

55,730

Loss on convertible note inducement

169

Income tax expense

571,793

Depletion, depreciation, amortization, and accretion

693,984

Impairment of oil and gas properties

100,654

Exploration

3,497

Equity-based compensation expense

28,470

Equity in earnings of unconsolidated affiliate

(74,327)

Dividends from unconsolidated affiliate

125,138

Contract termination, transaction expense and other

20,450

3,119,596

Martica related adjustments (1)

(161,101)

Adjusted EBITDAX

$

2,958,495

(1) 

Adjustments reflect noncontrolling interests in Martica not otherwise adjusted in amounts above. 

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):

Three Months Ended
September 30,

2021

2022

Drilling and completion costs (cash basis)

$

173,943

195,587

Change in accrued capital costs

(6,313)

31,539

Adjusted drilling and completion costs (accrual basis)

$

167,630

227,126

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 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, 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, impacts of world health event, including the COVID-19 pandemic, 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' Quarterly Report on Form 10-Q for the quarter ended September 30, 2022.

ANTERO RESOURCES CORPORATION

Condensed Consolidated Balance Sheets

(In thousands)

(Unaudited)

December 31,

September 30,

2021

2022

Assets

Current assets:

Accounts receivable

$

78,998

23,770

Accrued revenue

591,442

924,343

Derivative instruments

757

954

Other current assets

14,922

28,587

Total current assets

686,119

977,654

Property and equipment:

Oil and gas properties, at cost (successful efforts method):

Unproved properties

1,042,118

999,273

Proved properties

12,646,303

13,103,294

Gathering systems and facilities

5,802

5,802

Other property and equipment

116,522

129,853

13,810,745

14,238,222

Less accumulated depletion, depreciation and amortization

(4,283,700)

(4,587,529)

Property and equipment, net

9,527,045

9,650,693

Operating leases right-of-use assets

3,419,912

3,541,576

Derivative instruments

14,369

7,327

Investment in unconsolidated affiliate

232,399

222,882

Other assets

16,684

13,246

Total assets

$

13,896,528

14,413,378

Liabilities and Equity

Current liabilities:

Accounts payable

$

24,819

103,640

Accounts payable, related parties

76,240

74,584

Accrued liabilities

457,244

497,547

Revenue distributions payable

444,873

682,327

Derivative instruments

559,851

612,237

Short-term lease liabilities

456,347

535,347

Deferred revenue, VPP

37,603

32,330

Other current liabilities

11,140

6,010

Total current liabilities

2,068,117

2,544,022

Long-term liabilities:

Long-term debt

2,125,444

1,172,828

Deferred income tax liability, net

318,126

619,342

Derivative instruments

181,806

445,481

Long-term lease liabilities

2,964,115

3,007,636

Deferred revenue, VPP

118,366

95,514

Other liabilities

54,462

58,293

Total liabilities

7,830,436

7,943,116

Commitments and contingencies

Equity:

Stockholders' equity:

Preferred stock, $0.01 par value; authorized - 50,000 shares; none issued

Common stock, $0.01 par value; authorized - 1,000,000 shares; 313,930 shares and 303,131 shares issued and
     outstanding as of December 31, 2021 and September 30, 2022, respectively

3,139

3,031

Additional paid-in capital

6,371,398

5,941,977

Retained earnings (accumulated deficit)

(617,377)

266,468

Total stockholders' equity

5,757,160

6,211,476

Noncontrolling interests

308,932

258,786

Total equity

6,066,092

6,470,262

Total liabilities and equity

$

13,896,528

14,413,378

 

 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) (Unaudited)

(In thousands, except per share amounts)

Three Months
Ended September 30,

2021

2022

Revenue and other:

Natural gas sales

$

884,669

1,736,039

Natural gas liquids sales

598,327

620,816

Oil sales

56,734

67,025

Commodity derivative fair value losses

(1,250,466)

(530,523)

Marketing

232,685

159,985

Amortization of deferred revenue, VPP

11,404

9,478

Other income

530

1,804

Total revenue

533,883

2,064,624

Operating expenses:

Lease operating

25,363

27,453

Gathering, compression, processing and transportation

628,225

716,388

Production and ad valorem taxes

52,219

92,998

Marketing

266,751

185,377

Exploration and mine expenses

235

2,975

General and administrative (including equity-based compensation expense of $5,298 and
     $10,402 in 2021 and 2022, respectively)

32,442

42,903

Depletion, depreciation and amortization

182,810

169,607

Impairment of oil and gas properties

26,253

33,924

Accretion of asset retirement obligations

828

630

Contract termination

3,370

17,995

(Gain) loss on sale of assets

(539)

214

Total operating expenses

1,217,957

1,290,464

Operating income (loss)

(684,074)

774,160

Other income (expense):

Interest expense, net

(45,414)

(28,326)

Equity in earnings of unconsolidated affiliate

21,450

14,972

Loss on early extinguishment of debt

(16,567)

(30,307)

Loss on convertible note inducement

(169)

Transaction expense

(626)

Total other expense

(41,157)

(43,830)

Income (loss) before income taxes

(725,231)

730,330

Income tax benefit (expense)

158,656

(135,823)

Net income (loss) and comprehensive income (loss) including noncontrolling interests

(566,575)

594,507

Less: net income (loss) and comprehensive income (loss) attributable to noncontrolling
     interests

(17,257)

34,748

Net income (loss) and comprehensive income (loss) attributable to Antero Resources
     Corporation

$

(549,318)

559,759

Income (loss) per share—basic

$

(1.75)

1.83

Income (loss) per share—diluted

$

(1.75)

1.72

Weighted average number of shares outstanding:

Basic

313,790

305,343

Diluted

313,790

325,997

 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Cash Flows (Unaudited)

(In thousands)

Nine Months Ended
September 30,

2021

2022

Cash flows provided by (used in) operating activities:

Net income (loss) including noncontrolling interests

$

(1,112,130)

1,231,844

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

Depletion, depreciation, amortization and accretion

567,113

515,268

Impairments

69,618

79,749

Commodity derivative fair value losses

2,260,062

1,807,565

Losses on settled commodity derivatives

(481,083)

(1,484,660)

Payments for derivative monetizations

(4,569)

Deferred income tax expense (benefit)

(337,568)

307,326

Equity-based compensation expense

15,189

23,222

Equity in earnings of unconsolidated affiliate

(57,621)

(54,863)

Dividends of earnings from unconsolidated affiliate

105,325

93,854

Amortization of deferred revenue

(33,833)

(28,125)

Amortization of debt issuance costs, debt discount and debt premium

10,122

3,458

Settlement of asset retirement obligations

(946)

(Gain) loss on sale of assets

(2,827)

2,071

Loss on early extinguishment of debt

82,836

45,375

Loss on convertible note inducement and equitizations

50,777

169

Changes in current assets and liabilities:

Accounts receivable

(11,336)

55,229

Accrued revenue

(227,207)

(332,900)

Other current assets

(5,695)

(13,664)

Accounts payable including related parties

39,108

59,222

Accrued liabilities

124,382

36,632

Revenue distributions payable

117,819

237,453

Other current liabilities

16,470

(7,222)

Net cash provided by operating activities

1,184,952

2,576,057

Cash flows provided by (used in) investing activities:

Additions to unproved properties

(48,960)

(120,139)

Drilling and completion costs

(447,899)

(589,093)

Additions to other property and equipment

(14,082)

(12,188)

Proceeds from asset sales

3,192

1,147

Change in other assets

2,371

1,910

Change in other liabilities

(77)

Net cash used in investing activities

(505,455)

(718,363)

Cash flows provided by (used in) financing activities:

Repurchases of common stock

(675,412)

Issuance of senior notes

1,800,000

Repayment of senior notes

(1,424,354)

(1,011,313)

Borrowings (repayments) on bank credit facilities, net

(919,500)

9,000

Payment of debt issuance costs

(22,814)

(814)

Sale of noncontrolling interest

51,000

Distributions to noncontrolling interests in Martica Holdings LLC

(64,783)

(113,515)

Employee tax withholding for settlement of equity compensation awards

(12,706)

(65,029)

Convertible note inducement and equitizations

(85,648)

(169)

Other

(692)

(442)

Net cash used in financing activities

(679,497)

(1,857,694)

Net increase in cash and cash equivalents

Cash and cash equivalents, beginning of period

Cash and cash equivalents, end of period

$

Supplemental disclosure of cash flow information:

Cash paid during the period for interest

$

130,947

148,668

Increase in accounts payable and accrued liabilities for additions to property and equipment

$

33,547

23,633

 

The following table sets forth unaudited selected financial data for the three months ended September 30, 2021 and 2022:

Amount of

Three Months Ended September 30,

Increase

Percent

2021

2022

(Decrease)

Change

Revenue:

Natural gas sales

$

884,669

1,736,039

851,370

96

%

Natural gas liquids sales

598,327

620,816

22,489

4

%

Oil sales

56,734

67,025

10,291

18

%

Commodity derivative fair value losses

(1,250,466)

(530,523)

719,943

(58)

%

Marketing

232,685

159,985

(72,700)

(31)

%

Amortization of deferred revenue, VPP

11,404

9,478

(1,926)

(17)

%

Other income

530

1,804

1,274

240

%

Total revenue

533,883

2,064,624

1,530,741

287

%

Operating expenses:

Lease operating

25,363

27,453

2,090

8

%

Gathering and compression

218,815

239,868

21,053

10

%

Processing

207,093

241,347

34,254

17

%

Transportation

202,317

235,173

32,856

16

%

Production and ad valorem taxes

52,219

92,998

40,779

78

%

Marketing

266,751

185,377

(81,374)

(31)

%

Exploration and mine expenses

235

2,975

2,740

*

Impairment of oil and gas properties

26,253

33,924

7,671

29

%

Depletion, depreciation and amortization

182,810

169,607

(13,203)

(7)

%

Accretion of asset retirement obligations

828

630

(198)

(24)

%

General and administrative (excluding equity-based compensation)

27,144

32,501

5,357

20

%

Equity-based compensation

5,298

10,402

5,104

96

%

Contract termination

3,370

17,995

14,625

*

Gain (loss) on sale of assets

(539)

214

753

*

Total operating expenses

1,217,957

1,290,464

72,507

6

%

Operating income (loss)

(684,074)

774,160

1,458,234

*

Other earnings (expenses):

Interest expense, net

(45,414)

(28,326)

17,088

(38)

%

Equity in earnings of unconsolidated affiliate

21,450

14,972

(6,478)

(30)

%

Loss on early extinguishment of debt

(16,567)

(30,307)

(13,740)

83

%

Loss on convertible note inducement

(169)

(169)

*

Transaction expenses

(626)

626

*

Total other expense

(41,157)

(43,830)

(2,673)

6

%

Income (loss) before income taxes

(725,231)

730,330

1,455,561

*

Income tax benefit (expense)

158,656

(135,823)

(294,479)

*

Net income (loss) and comprehensive income (loss) including noncontrolling interests

(566,575)

594,507

1,161,082

*

Less: net income (loss) and comprehensive income (loss) attributable to noncontrolling interests

(17,257)

34,748

52,005

*

Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation

$

(549,318)

559,759

1,109,077

*

Adjusted EBITDAX

$

358,199

878,100

519,901

145

%

 

* Not meaningful

 

The following table sets forth selected operating data for the three months ended September 30, 2021 and 2022:

Amount of

Three Months Ended September 30,

Increase

Percent

2021

2022

(Decrease)

Change

Production data (1) (2):

Natural gas (Bcf)

205

200

(5)

(2)

%

C2 Ethane (MBbl)

4,372

5,010

638

15

%

C3+ NGLs (MBbl)

10,258

9,950

(308)

(3)

%

Oil (MBbl)

932

804

(128)

(14)

%

Combined (Bcfe)

299

294

(5)

(2)

%

Daily combined production (MMcfe/d)

3,247

3,200

(47)

(1)

%

Average prices before effects of derivative settlements (3):

Natural gas (per Mcf)

$

4.31

8.69

4.38

102

%

C2 Ethane (per Bbl)

$

13.25

23.40

10.15

77

%

C3+ NGLs (per Bbl)

$

52.68

50.61

(2.07)

(4)

%

Oil (per Bbl)

$

60.87

83.41

22.54

37

%

Weighted Average Combined (per Mcfe)

$

5.15

8.23

3.08

60

%

Average realized prices after effects of derivative settlements (3):

Natural gas (per Mcf)

$

3.00

5.51

2.51

84

%

C2 Ethane (per Bbl)

$

13.25

23.40

10.15

77

%

C3+ NGLs (per Bbl)

$

38.67

50.27

11.60

30

%

Oil (per Bbl)

$

56.31

82.76

26.45

47

%

Weighted Average Combined (per Mcfe)

$

3.79

6.06

2.27

60

%

Average costs (per Mcfe):

Lease operating

$

0.08

0.09

0.01

13

%

Gathering and compression

$

0.73

0.81

0.08

11

%

Processing

$

0.69

0.82

0.13

19

%

Transportation

$

0.68

0.80

0.12

18

%

Production and ad valorem taxes

$

0.17

0.32

0.15

88

%

Marketing (revenue) expense, net

$

0.11

0.09

(0.02)

(18)

%

Depletion, depreciation, amortization and accretion

$

0.61

0.58

(0.03)

(5)

%

General and administrative (excluding equity-based compensation)

$

0.09

0.11

0.02

22

%

 

(1)

Production volumes exclude volumes related to VPP transaction.

(2) 

Oil and NGLs production was converted at 6 Mcf per Bbl to calculate total Bcfe production and per Mcfe amounts.  This ratio is an estimate of the equivalent energy content of the products and may not reflect their relative economic value.

(3) 

Average prices reflect the before and after effects of our settled commodity derivatives.  Our calculation of such after effects includes gains on settlements of commodity derivatives, which do not qualify for hedge accounting because we do not designate or document them as hedges for accounting purposes.

 

Cision View original content to download multimedia:https://www.prnewswire.com/news-releases/antero-resources-reports-third-quarter-2022-results-and-increases-share-repurchase-program-by-1-billion-301660454.html

SOURCE Antero Resources Corporation