Antero Resources · Earnings release · 8-K Exhibit 99

Exhibit

Antero Resources Announces Fourth Quarter 2025

Denver, Colorado, February 11, 2026—Antero

Resources Corporation (NYSE: AR) (“Antero Resources,” “Antero,” or the “Company”) today announced

its fourth quarter 2025 financial and operating results, year end 2025 estimated proved reserves and 2026 guidance. The relevant consolidated

financial statements are included in Antero Resources’ Annual Report on Form 10-K for the year ended December 31, 2025.

Fourth Quarter 2025 Highlights:

·

Net production averaged 3.5 Bcfe/d, 2% increase from the year ago period

·

Realized a pre-hedge natural gas equivalent price of $3.97 per Mcfe, a $0.42 per Mcfe premium to NYMEX

·

Realized a pre-hedge C3+ NGL price of $35.41 per barrel, a $1.52 per barrel premium to Mont Belvieu

·

Net income was $194 million and Adjusted Net Income was $133 million (Non-GAAP)

·

Adjusted EBITDAX was $422 million (Non-GAAP); net cash provided by operating activities was $371 million

·

Adjusted Free Cash Flow before changes in working capital was $204 million (Non-GAAP)

·

T1Achieved a company record averaging 16.1 stages per day over an entire pad

·

Closed previously announced HG acquisition in early February

·

T2Production expected to average 4.1 Bcfe/d on $1 billion of D&C capital, including $900 million

of maintenance capital and $100 million associated with not entering into a drilling joint venture in 2026

o

The $100 million of incremental capital is expected to increase 2027 production to 4.3 Bcfe/d

·

In addition to the $1.0 billion, depending on commodity prices, Antero could invest up to $200 million

of discretionary growth capital, which could increase production up to 4.5 Bcfe/d in 2027

Michael Kennedy, CEO and President of Antero Resources

commented, “2025 was a pivotal year for Antero as we took significant steps in increasing our production and drilling inventory.

During the year we completed a transaction to acquire higher working interest in our wells, followed by the largest acquisition in our

company’s history, acquiring our West Virginia peer, HG Energy. T3The recent closing of the HG Energy acquisition was ahead of schedule

and will increase our scale and dry gas exposure. This larger production base and inventory positions Antero to T4capture the significant

demand opportunities that are expected from LNG exports, data centers and natural gas fired power plants.”

Mr. Kennedy continued, “Our 2026 budget

highlights these transformational changes as our production base increases from 3.4 Bcfe/d in 2025 to more than 4.2 Bcfe/d by year end

2026. We intend to run 3 drilling rigs and 2 completion crews, which provides us with the optionality to grow our production base further

if supported by the commodity price backdrop and in basin demand opportunities.”

Brendan Krueger, CFO of Antero Resources added,

“The closing of the HG Energy acquisition T5immediately improves our competitive positioning by significantly reducing our cost structure

and increases our local dry gas exposure. These higher margins are hedged and are expected to drive a substantial increase in Adjusted

Free Cash Flow and T6reduce leverage to under 1.0x during the year. T7We intend to remain focused on debt reduction and continuing to opportunistically

repurchase shares.”

For a discussion of the non-GAAP financial

measures including Adjusted Net Income, Adjusted EBITDAX, Adjusted Free Cash Flow and Net Debt, please see “Non-GAAP Financial Measures.”

1

Transaction Updates

The HG Energy acquisition closed in February 2026.

The Ohio Utica Shale divestiture is expected to close by the end of February 2026. The timing of these transactions are reflected in the

Antero’s 2026 drilling and completion capital

budget is $1 billion and includes $900 million for maintenance capital and $100 million of capital related to not electing to enter into

a drilling joint venture during the year. Discretionary growth capital up to $200 million will be based on the commodity price outlook

and in basin demand needs throughout the year. This growth capital reflects completing an additional two to three pads in 2026, which

could increase production to approximately 4.5 Bcfe/d in 2027. First quarter 2026 production is expected to average approximately 3.8

Bcfe/d, with the second quarter increasing to 4.1 Bcfe/d driven by a full quarter of HG contribution. The second half of 2026 is expected

to average approximately 4.2 Bcfe/d. This results in a full year average of approximately 4.1 Bcfe/d. The Company’s land capital

guidance is $100 million.

The following is a summary of Antero Resources’ 2026 capital budget.

Capital Budget ($ in Millions)

Drilling & Completion Maintenance Capital

Drilling & Completion No Drilling JV Capital

Total D&C Capital

Drilling & Completion Discretionary Growth Capital

Land Capital

# of Wells

Net Wells

Average Lateral

Length (Feet)

Completed Wells (Net)

The following is a summary of Antero Resources’ 2026 production,

pricing and cash expense guidance:

Production Guidance

Net Daily Natural Gas Equivalent Production (Bcfe/d)

Net Daily Natural Gas Production (Bcf/d)

Total Net Daily Liquids Production (MBbl/d):

Net Daily C3+ NGL Production (MBbl/d)

Net Daily Ethane Production (MBbl/d)

Net Daily Oil Production (MBbl/d)

8

Realized Pricing Guidance (Before Hedges)

Low

High

Natural Gas Realized Price Premium vs. NYMEX Henry Hub ($/Mcf)

$

$

C3+ NGL Realized Price Premium/(Discount) vs. Mont Belvieu ($/Bbl)

$

)

$

Ethane Realized Price Premium vs. Mont Belvieu ($/Bbl)

$

$

Oil Realized Price (Differential) vs. WTI Oil ($/Bbl)

$

)

$

)

Cash Expense Guidance

Low

High

Cash Production Expense ($/Mcfe)(1)

$

$

Marketing Expense, Net of Marketing Revenue ($/Mcfe)

$

$

G&A Expense ($/Mcfe)(2)

$

$

(1)

Includes lease operating, gathering, compression, processing and transportation expenses (“GP&T”)

and production and ad valorem taxes.

(2)

Excludes equity-based compensation.

2

Adjusted Free Cash Flow

During the fourth quarter of 2025, Adjusted Free

Cash Flow before Changes in Working Capital was $204 million.

Three Months Ended

Net cash provided by operating activities

$

Less: Capital expenditures

)

)

Less: Distributions to non-controlling interests in Martica

)

)

Plus: Transaction expense

—

Adjusted Free Cash Flow

$

Changes in Working Capital

Adjusted Free Cash Flow before Changes in Working Capital

$

Fourth Quarter 2025 Financial Results

Net daily natural gas equivalent production in

the fourth quarter averaged 3.5 Bcfe/d, including 208 MBbl/d of liquids. Antero’s average realized natural gas price before hedges

was $3.71 per Mcf, a $0.16 per Mcf premium to the benchmark index price. Antero’s average realized C3+ NGL price before hedges was

$35.41 per barrel, representing a $1.52 per barrel premium to the benchmark index price.

The following table details average net production

and average realized prices for the three months ended December 31, 2025:

Natural Gas

Oil

C3+ NGLs

Ethane

Combined

Natural Gas

Equivalent

(MMcf/d)

(Bbl/d)

(Bbl/d)

(Bbl/d)

(MMcfe/d)

Average Net Production

Natural Gas

Oil

C3+ NGLs

Ethane

Combined Natural Gas Equivalent

Average Realized Prices

($/Mcf)

($/Bbl)

($/Bbl)

($/Bbl)

($/Mcfe)

Average realized prices before settled derivatives (1)

$

Index price (1)

$

Premium / (Discount) to Index price

$

)

Settled commodity derivatives

$

—

—

—

Average realized prices after settled derivatives (1)

$

Premium / (Discount) to Index price

$

)

(1)

Please see the Company’s Annual Report on Form 10-K for the year ended December 31, 2025 for

more information on these index and average realized prices.

All-in cash expense, which includes lease operating,

gathering, compression, processing and transportation and production and ad valorem taxes was $2.56 per Mcfe in the fourth quarter, as

compared to $2.45 per Mcfe during the fourth quarter of 2024. Net marketing expense was $0.04 per Mcfe during the fourth quarter of 2025,

Fourth Quarter 2025 Operating Results

Antero placed 18 Marcellus wells to sales during

the fourth quarter with an average lateral length of 12,500 feet. Twelve of these wells have been on line for approximately 60

days with an average rate per well of 25 MMcfe/d, including 1,410 Bbl/d of liquids per well assuming 25% ethane recovery. In addition,

Antero set a number of company operational records, including:

·

One completion crew completed 19 stages in a single day

·

Averaged 16.1 stages per day for an entire pad

·

One completion crew recorded 457 stages completed in a calendar month with 651 pumping hours

3

Fourth Quarter 2025 Capital Investment

Antero’s drilling and completion capital

expenditures for the three months ended December 31, 2025 were $159 million. In addition to capital invested in drilling and completion

activities, the Company invested $33 million in land during the fourth quarter. Through this investment, Antero added approximately 7,000

net acres, representing 26 incremental drilling locations at an average cost of approximately $900,000 per location. During 2025, Antero’s

organic leasing program has added 102 incremental drilling locations at an average cost of approximately $925,000 per location, more than

offsetting the 78 gross locations drilled during the year.

Natural Gas Hedge Program

Antero added natural gas swaps and basis hedges

for the full years 2026 and 2027, including positions acquired from HG Energy, in order to support its acquisition and development program.

For more information on our hedge portfolio, please see the presentation titled “Hedges and Guidance Presentation” on Antero’s

website. The hedges below include positions executed through February 6, 2026 and reflect Antero stand-alone for the month of January

2026 and inclusive of HG hedges from February to December 2026.

Swaps

Natural Gas

(MMBtu/d)

Weighted

Average Index

Price ($/MMBtu)

January 2026 NYMEX Henry Hub Swap

$

February – December 2026 NYMEX Henry Hub Swap

$

$

Weighted Average Index

Collars

Natural Gas

(MMBtu/d)

Floor Price

($/MMBtu)

Ceiling Price

($/MMBtu)

January 2026 NYMEX Henry Hub Costless Collars

$

$

February – December 2026 NYMEX Henry Hub Costless Collars

$

$

2027 NYMEX Henry Hub Costless Collars

$

$

Year End Proved Reserves

At December 31, 2025, Antero’s estimated

proved reserves were 19.1 Tcfe, a 7% increase from the prior year. Estimated proved reserves were comprised of 61% natural gas, 38% NGLs

and 1% oil.

Estimated proved developed reserves were 14.4

Tcfe. At year end 2025, Antero’s five year development plan included 296 gross PUD locations. Antero's proved undeveloped locations

have an average estimated BTU of 1215, with an average lateral length of 14,650 feet.

Antero's 4.7 Tcfe of estimated proved undeveloped

reserves will require an estimated $2.3 billion of future development capital over the next five years, resulting in an estimated average

future development cost for proved undeveloped reserves of $0.49 per Mcfe.

The following table presents a summary of changes

in estimated proved reserves (in Tcfe).

Extensions, discoveries and other additions

Revisions of previous estimates

Revisions to five-year development plan

Price revisions

Acquisition of reserves

Production

)

4

Conference Call

A conference call is scheduled on Thursday, February

12, 2026 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, February 19, 2026 at 9:00 am

MT at 877-660-6853 (U.S.) or 201-612-7415 (International) using the conference ID: 13758128. 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

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):

Three Months Ended December 31,

Net income and comprehensive income attributable to Antero Resources Corporation

$

Net income and comprehensive income attributable to noncontrolling interests

Unrealized commodity derivative (gains) losses

)

Amortization of deferred revenue, VPP

)

)

Loss (gain) on sale of assets

)

Impairment of property and equipment

Equity-based compensation

Equity in earnings of unconsolidated affiliate

)

)

Contract termination and loss contingency

Transaction expense

—

Tax effect of reconciling items (1)

)

Martica adjustments (2)

)

)

Adjusted Net Income

$

Diluted Weighted Average Common Shares Outstanding (3)

(1)

(2)

Adjustments reflect noncontrolling interests 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 per share. Anti-dilutive weighted average shares outstanding for the three months ended

December 31, 2024 were 0.3 million. There were no anti-dilutive weighted average shares outstanding for the three months ended December

5

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):

Credit Facility

$

—

Unamortized debt issuance costs

)

)

Total long-term debt

$

Less: Cash, cash equivalents and restricted cash

—

)

Net Debt

$

Adjusted Free Cash Flow

Adjusted 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 Adjusted Free Cash Flow as net

cash provided by operating activities, less capital expenditures, which includes additions to unproved properties, drilling and completion

costs and additions to other property and equipment, less distributions to non-controlling interests in Martica, plus transaction expenses.

The Company has not provided projected net cash

provided by operating activities or a reconciliation of Adjusted 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.

Adjusted Free Cash Flow is a useful indicator

of the Company’s ability to internally fund its activities, service or incur additional debt and estimate our ability to return

capital to shareholders. There are significant limitations to using Adjusted 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 Adjusted Free Cash Flow

reported by different companies. Adjusted 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, 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.

6

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 and net cash provided by operating activities. The following table represents a reconciliation of Antero’s

net income, including noncontrolling interest, to Adjusted EBITDAX and a reconciliation of Antero’s Adjusted EBITDAX to net cash

provided by operating activities per our condensed consolidated statements of cash flows, in each case, for the three months ended December

31, 2024 and 2025 (in thousands). Adjusted EBITDAX also excludes the noncontrolling interests in Martica, and these adjustments are disclosed

in the table below as Martica related adjustments.

(1)

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

Three Months Ended December 31,

Reconciliation of net income to Adjusted EBITDAX:

Net income and comprehensive income attributable to Antero Resources Corporation

$

Net income and comprehensive income attributable to noncontrolling interests

Unrealized commodity derivative (gains) losses

)

Amortization of deferred revenue, VPP

)

)

Loss (gain) on sale of assets

)

Interest expense, net

Loss on early extinguishment of debt

—

—

Income tax expense (benefit)

)

Depletion, depreciation, amortization and accretion

Impairment of property and equipment

Exploration expense

Equity-based compensation expense

Equity in earnings of unconsolidated affiliate

)

)

Dividends from unconsolidated affiliate

Contract termination, loss contingency and settlements

Transaction expense and other

Martica related adjustments (1)

)

)

Adjusted EBITDAX

$

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

Adjusted EBITDAX

$

Martica related adjustments (1)

Interest expense, net

)

)

Amortization of debt issuance costs and other

Exploration expense

)

)

Changes in current assets and liabilities

)

)

Contract termination, loss contingency and settlements

)

Transaction expense and other

)

)

Net cash provided by operating activities

$

(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

Drilling and completion costs (cash basis)

$

Change in accrued capital costs

)

Adjusted drilling and completion costs (accrual basis)

$

7

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.

This release includes "forward-looking

statements." Words such as “may,” “assume,” “forecast,” “position,” “predict,”

“strategy,” “expect,” “intend,” “plan,” “estimate,” “anticipate,”

“believe,” “project,” “budget,” “potential,” or “continue,” “goal,”

“target,” and similar expressions are used to identify forward-looking statements, although not all forward-looking statements

contain such identifying words. 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

financial strategy, future operating results, financial position, estimated revenues and losses, potential acquisitions, dispositions

or other strategic transactions, including the pending Ohio Utica Shale divestiture, the timing thereof, and our ability to integrate

acquired assets and achieve the intended operational, financial and strategic benefits from any such transactions, projected costs, estimated

realized natural gas, NGL and oil prices, prospects, plans and objectives of management, return of capital program, expected results,

impacts of geopolitical, including the conflicts in Ukraine and in the Middle East, and world health events, future commodity prices,

future production targets, 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, expected drilling and development plans, projected well

costs and cost savings initiatives, operations of Antero Midstream, 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, the impact of recently enacted legislation, 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. These forward-looking

statements are based on management’s current beliefs, based on currently available information, as to the outcome and timing of

future events. 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, incidental to our business, 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, availability 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, changes in

emission calculation methods, 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, including the conflicts in Ukraine and the Middle East, and world health events, cybersecurity risks, the state

of markets for, and availability of, verified quality carbon offsets and the other risks described under the heading " Risk Factors"

in Antero Resources’ Annual Report on Form 10-K for the year ended December 31, 2025.

For more information, contact Daniel Katzenberg,

Director - Finance and Investor Relations of Antero Resources at (303) 357-7219 or dkatzenberg@anteroresources.com.

8

ANTERO RESOURCES CORPORATION

Consolidated Balance Sheets

(In thousands, except per share amounts)

Assets

Current assets:

Restricted cash

$

—

Accounts receivable

Accrued revenue

Derivative instruments

Prepaid expenses

Current assets held for sale

—

Other current assets

Total current assets

Property and equipment:

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

Unproved properties

Proved properties

Gathering systems and facilities

—

Other property and equipment

Less accumulated depletion, depreciation and amortization

)

)

Property and equipment, net

Operating leases right-of-use assets

Derivative instruments

Investment in unconsolidated affiliate

Assets held for sale

—

Other assets

Total assets

$

Liabilities and Equity

Current liabilities:

Accounts payable

$

Accounts payable, related parties

Accrued liabilities

Revenue distributions payable

Derivative instruments

—

Short-term lease liabilities

Deferred revenue, VPP

Current liabilities held for sale

—

Other current liabilities

Total current liabilities

Long-term liabilities:

Long-term debt

Deferred income tax liability, net

Derivative instruments

—

Long-term lease liabilities

Deferred revenue, VPP

Liabilities held for sale

—

Other liabilities

Total liabilities

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; 311,165 and 308,510 shares issued and outstanding as of December 31, 2024 and December 31, 2025, respectively

Additional paid-in capital

Retained earnings

Total stockholders' equity

Noncontrolling interests

Total equity

Total liabilities and equity

$

9

ANTERO RESOURCES CORPORATION

Consolidated Statements of Operations and Comprehensive

Income

(In thousands, except per share amounts)

(Unaudited)

Three Months Ended

Year Ended

Revenue and other:

Natural gas sales

$

Natural gas liquids sales

Oil sales

Commodity derivative fair value gains (losses)

)

Marketing

Amortization of deferred revenue, VPP

Other revenue and income

Total revenue

Operating expenses:

Lease operating

Gathering, compression, processing and transportation

Production and ad valorem taxes

Marketing

Exploration and mine expenses

General and administrative (including equity-based compensation expense)

Depletion, depreciation and amortization

Impairment of property and equipment

Accretion of asset retirement obligations

Contract termination, loss contingency and settlements

Gain on sale of assets

)

)

Other operating expense

Total operating expenses

Operating income

Other income (expense):

Interest expense, net

)

)

)

)

Equity in earnings of unconsolidated affiliate

Loss on early extinguishment of debt

—

—

)

)

Transaction expense

—

)

—

)

Total other expense

)

)

)

Income before income taxes

)

Income tax benefit (expense)

)

)

Net income and comprehensive income including noncontrolling interests

Less: net income and comprehensive income attributable to noncontrolling interests

Net income and comprehensive income attributable to Antero Resources Corporation

$

Net income per common share—basic

$

Net income per common share—diluted

$

Weighted average number of common shares outstanding:

Basic

Diluted

ANTERO RESOURCES CORPORATION

Consolidated Statements of Cash Flows

(In thousands)

Year Ended December 31,

Cash flows provided by (used in) operating activities:

Net income including noncontrolling interests

$

Adjustments to reconcile net income to net cash provided by operating activities:

Depletion, depreciation, amortization and accretion

Impairment of property and equipment

Commodity derivative fair value gains

)

)

)

Settled commodity derivative gains (losses)

)

)

Payments for derivative monetizations

)

—

—

Deferred income tax expense (benefit)

)

Equity-based compensation expense

Equity in earnings of unconsolidated affiliate

)

)

)

Dividends of earnings from unconsolidated affiliate

Amortization of deferred revenue

)

)

)

Amortization of debt issuance costs and other

Settlement of asset retirement obligations

)

)

)

Contract termination, loss contingency and settlements

Loss (gain) on sale of assets

)

)

Loss on early extinguishment of debt

—

Loss on convertible note inducements

—

—

Changes in current assets and liabilities:

Accounts receivable

)

Accrued revenue

)

)

Prepaid expenses and other current assets

)

Accounts payable including related parties

)

)

Accrued liabilities

)

)

Revenue distributions payable

)

)

Other current liabilities

)

Net cash provided by operating activities

Cash flows provided by (used in) investing activities:

Additions to unproved properties

)

)

)

Drilling and completion costs

)

)

)

Additions to other property and equipment

)

)

)

Acquisitions of oil and gas properties

—

—

)

Proceeds from asset sales

Change in other assets

)

)

)

Net cash used in investing activities

)

)

)

Cash flows provided by (used in) financing activities:

Repurchases of common stock

)

—

)

Repayment of senior notes

—

—

)

Borrowings on Credit Facility

Repayments on Credit Facility

)

)

)

Payment of debt issuance costs

)

)

)

Distributions to noncontrolling interests

)

)

)

Employee tax withholding for settlement of equity-based compensation awards

)

)

)

Convertible note inducements

)

—

—

Other

)

)

)

Net cash provided by (used in) financing activities

)

)

Net increase in cash, cash equivalents and restricted cash

—

—

Cash, cash equivalents and restricted cash, beginning of period

—

—

—

Cash, cash equivalents and restricted cash, end of period

$

—

—

Supplemental disclosure of cash flow information:

Cash paid during the period for interest

$

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

$

)

)

Increase in other current liabilities for acquisitions of oil and gas properties

$

—

—

The following table sets forth selected financial data for the three

(Unaudited)

Three Months Ended

Amount of

Increase

Percent

(Decrease)

Change

Revenue:

Natural gas sales

$

%

Natural gas liquids sales

)

)%

Oil sales

)

)%

Commodity derivative fair value gains (losses)

)

*

Marketing

)

(7

)%

Amortization of deferred revenue, VPP

)

(7

)%

Other revenue and income

6

%

Total revenue

%

Operating expenses:

Lease operating

4

%

Gathering and compression

8

%

Processing

9

%

Transportation

%

Production and ad valorem taxes

)

)%

Marketing

)

)%

Exploration

%

General and administrative (excluding equity-based compensation)

)

(1

)%

Equity-based compensation

)

)%

Depletion, depreciation and amortization

)

(3

)%

Impairment of property and equipment

)

)%

Accretion of asset retirement obligations

)

)%

Contract termination and loss contingency

%

Loss (gain) on sale of assets

)

)

*

Other operating expense

5

%

Total operating expenses

1

%

Operating income

%

Other earnings (expenses):

Interest expense, net

)

)

)%

Equity in earnings of unconsolidated affiliate

)

)%

Transaction expenses

—

)

)

*

Total other expense

)

)

)

%

Income before income taxes

%

Income tax (expense) benefit

)

)

*

Net income and comprehensive income including noncontrolling interests

%

Less: net income and comprehensive income attributable to noncontrolling interests

1

%

Net income and comprehensive income attributable to Antero Resources Corporation

$

%

Adjusted EBITDAX

$

%

* Not meaningful

The following table sets forth selected financial data for the three

Unaudited

Three Months Ended

Amount of

Increase

Percent

(Decrease)

Change

Production data (1) (2):

Natural gas (Bcf)

6

%

C2 Ethane (MBbl)

)

)%

C3+ NGLs (MBbl)

1

%

Oil (MBbl)

)

)%

Combined (Bcfe)

7

2

%

Daily combined production (MMcfe/d)

2

%

Average prices before effects of derivative settlements (3):

Natural gas (per Mcf)

$

%

C2 Ethane (per Bbl)

$

%

C3+ NGLs (per Bbl)

$

)

)%

Oil (per Bbl)

$

)

)%

Weighted Average Combined (per Mcfe)

$

9

%

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

Natural gas (per Mcf)

$

%

C2 Ethane (per Bbl)

$

%

C3+ NGLs (per Bbl)

$

)

)%

Oil (per Bbl)

$

)

)%

Weighted Average Combined (per Mcfe)

$

%

Average costs (per Mcfe):

Lease operating

$

—

*

Gathering and compression

$

6

%

Processing

$

6

%

Transportation

$

%

Production and ad valorem taxes

$

)

)%

Marketing expense, net

$

)

)%

General and administrative (excluding equity-based compensation)

$

—

*

Depletion, depreciation, amortization and accretion

$

)

(6

)%

* Not meaningful

(1)

Production data excludes 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 (losses) 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.