0001433270
false
0001433270
2023-07-26
2023-07-26
iso4217:USD
xbrli:shares
iso4217:USD
xbrli:shares
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of
the Securities Exchange Act of 1934
Date of report (Date of earliest event reported):
July 26, 2023
ANTERO RESOURCES CORPORATION
(Exact name of registrant as specified in its charter)
| Delaware |
|
001-36120 |
|
80-0162034 |
(State or Other
Jurisdiction
of Incorporation) |
|
(Commission
File Number) |
|
(I.R.S. Employer
Identification Number) |
1615 Wynkoop Street
Denver, Colorado 80202
(Address of Principal Executive Offices) (Zip Code)
Registrant’s
Telephone Number, Including Area Code: (303)
357-7310
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
| ¨ | Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) |
| ¨ | Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) |
| ¨ | Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) |
| ¨ | Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) |
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class |
|
Trading
symbol(s) |
|
Name of each exchange on which
registered |
| Common
Stock, par value $0.01 Per Share |
|
AR |
|
New
York Stock Exchange |
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging growth company ¨
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
| Item 2.02 |
Results of Operations and Financial Condition |
On July 26,
2023, Antero Resources Corporation issued a press release, a copy of which is attached hereto as Exhibit 99.1 and incorporated by
reference herein, announcing its financial and operational results for the quarter ended June 30, 2023.
The information
in this Current Report, including Exhibit 99.1, is being furnished pursuant to Item 2.02 of Form 8-K and shall not be deemed
“filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”),
or otherwise subject to liabilities of that section, and is not incorporated by reference into any filing under the Securities Act of
1933, as amended, or the Exchange Act unless specifically identified therein as being incorporated therein by reference.
| Item 9.01 |
Financial Statements and Exhibits. |
(d) Exhibits.
SIGNATURES
Pursuant to the requirements of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
| |
ANTERO RESOURCES CORPORATION |
| |
|
|
| |
By: |
/s/ Michael N. Kennedy |
| |
|
Michael N. Kennedy |
| |
|
Chief Financial Officer and Senior Vice President – Finance |
Dated: July 26, 2023
Exhibit 99.1
Antero Resources Announces Second Quarter 2023
Financial and Operational Results and Increased Production Guidance
Denver,
Colorado, July 26, 2023—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 |
| o | Liquids production averaged 192 MBbl/d, an increase of 16% from the year ago period |
| o | 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 |
| o | Realized a C3+ NGL price of $34.16 per barrel |
| o | 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 $0.10 per Mcf due to the lower natural gas strip that
reduces the BTU uplift Antero realizes.
| | |
Full Year 2023 –
Prior | | |
Full Year 2023 –
Revised | |
| Full Year 2023 Guidance | |
Low | | |
High | | |
Low | | |
High | |
| Net Production (Bcfe/d) | |
| 3.25 | | |
| 3.30 | | |
| 3.35 | | |
| 3.4 | |
| Net Natural Gas Production (Bcf/d) | |
| 2.10 | | |
| 2.15 | | |
| 2.2 | | |
| 2.225 | |
| Net Liquids Production (Bbl/d) | |
| 184,000 | | |
| 195,000 | | |
| 188,000 | | |
| 199,000 | |
| Net Daily C3+ NGL Production | |
| 105,000 | | |
| 110,000 | | |
| 110,000 | | |
| 115,000 | |
| Net Daily Ethane Production (Bbl/d) | |
| 70,000 | | |
| 75,000 | | |
| 67,500 | | |
| 72,500 | |
| Net Daily Oil Production (Bbl/d) | |
| 9,000 | | |
| 10,000 | | |
| 10,500 | | |
| 11,500 | |
| | |
| | | |
| | | |
| | | |
| | |
| Cash Production Expense ($/Mcfe) | |
$ | 2.40 | | |
$ | 2.50 | | |
$ | 2.35 | | |
$ | 2.45 | |
| Natural Gas Realized Price Expected Premium to NYMEX ($/Mcf) | |
$ | 0.05 | | |
$ | 0.15 | | |
$ | 0.00 | | |
$ | 0.10 | |
Note: Any 2023 guidance items not discussed in this release are
unchanged from previously stated guidance.
Free Cash Flow
During the second quarter of 2023, Free Cash
Flow was ($159) million.
| | |
Three Months Ended
June 30, | |
| | |
2022 | | |
2023 | |
| Net cash provided by operating activities | |
$ | 922,712 | | |
| 155,263 | |
| Less: Net cash used in investing activities | |
| (259,717 | ) | |
| (287,236 | ) |
| Plus: Contract termination | |
| 2,096 | | |
| 4,441 | |
| Less: Proceeds from sale of assets, net | |
| — | | |
| (220 | ) |
| Less: Distributions to non-controlling interests in Martica | |
| (31,541 | ) | |
| (31,745 | ) |
| Free Cash Flow | |
$ | 633,550 | | |
| (159,497 | ) |
| Changes in Working Capital (1) | |
| 32,279 | | |
| (52,709 | ) |
| Free Cash Flow before Changes in Working Capital | |
$ | 665,829 | | |
| (212,206 | ) |
| (1) | Working capital adjustments in the second quarter of 2022 include a decrease of $43 million in changes
in current assets and liabilities and an increase of $11 million in accounts payable and accrued liabilities for additions to property
and equipment. Working capital adjustments in the second quarter of 2023 include a $51 million net increase in current assets and liabilities
and a $2 million increase in accounts payable and accrued liabilities for additions to property and equipment. |
During the first half of 2023, Free Cash Flow
was $14 million.
| | |
Six Months Ended June 30, | |
| | |
2022 | | |
2023 | |
| Net cash provided by operating activities | |
$ | 1,488,385 | | |
| 499,165 | |
| Less: Net cash used in investing activities | |
| (474,834 | ) | |
| (638,040 | ) |
| Plus: Payments for derivative monetizations | |
| — | | |
| 202,339 | |
| Plus: Contract termination | |
| 2,104 | | |
| 33,991 | |
| Less: Proceeds from sale of assets, net | |
| (195 | ) | |
| (311 | ) |
| Less: Distributions to non-controlling interests in Martica | |
| (67,298 | ) | |
| (83,084 | ) |
| Free Cash Flow | |
$ | 948,162 | | |
| 14,060 | |
| Changes in Working Capital (1) | |
| 182,753 | | |
| (202,474 | ) |
| Free Cash Flow before Changes in Working Capital | |
$ | 1,130,915 | | |
| (188,414 | ) |
| (1) | Working capital adjustments in
the first half of 2022 include decreases of $179 million and $4 million for changes in current
assets and liabilities and accounts payable and accrued liabilities for additions to property
and equipment. Working capital adjustments in the first half of 2023 include a $211 million
net increase in current assets and liabilities and a $9 million decrease in accounts payable
and accrued liabilities for additions to property and equipment. |
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
$1 billion of remaining capacity under the announced share repurchase program.
| |
|
Program to Date
1Q22 – 2Q23 |
|
|
Second Quarter
2023 |
|
| Total shares purchased (MM) (1) |
|
|
31.1 |
|
|
|
0.7 |
|
| Share purchases ($MM) |
|
|
1,043 |
|
|
|
16 |
|
| % of common shares outstanding (2) |
|
|
10 |
% |
|
|
NM |
|
| (1) | The total shares purchased during the period ended January 1, 2022 through June 30, 2023
and three months ended June 30, 2023 includes 3.2 million and 0.7 million shares of our common stock, respectively, related to satisfying
tax withholding obligations incurred upon the vesting of equity awards held by our employees. |
| (2) | Shares outstanding as of June 30, 2023. |
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 $0.04 per Mcf premium to the average first-of-month (“FOM”)
NYMEX Henry Hub price.
The following table details average net production
and average realized prices for the three months ended June 30, 2023:
| | | |
Three Months Ended June 30, 2023 | |
| | | |
Natural
Gas
(MMcf/d) | | |
Oil
(Bbl/d) | | |
C3+ NGLs
(Bbl/d) | | |
Ethane
(Bbl/d) | | |
Natural
Gas
Equivalent
(MMcfe/d) | |
| Average Net Production | | |
| 2,242 | | |
| 10,670 | | |
| 111,813 | | |
| 70,484 | | |
| 3,400 | |
| | |
| | |
| | |
| | |
| | |
Combined | |
| | |
| | |
| | |
| | |
| | |
Natural | |
| | |
| | |
| | |
| | |
| | |
Gas | |
| | |
Natural Gas | | |
Oil | | |
C3+ NGLs | | |
Ethane | | |
Equivalent | |
| Average Realized Prices | |
($/Mcf) | | |
($/Bbl) | | |
($/Bbl) | | |
($/Bbl) | | |
($/Mcfe) | |
| Average realized prices before settled derivatives | |
$ | 2.14 | | |
$ | 59.69 | | |
$ | 34.16 | | |
$ | 7.82 | | |
$ | 2.89 | |
| NYMEX average price (1) | |
$ | 2.10 | | |
$ | 73.78 | | |
| | | |
| | | |
$ | 2.10 | |
| Premium / (Discount) to NYMEX | |
$ | 0.04 | | |
$ | (14.09 | ) | |
| | | |
| | | |
$ | 0.79 | |
| | |
| | | |
| | | |
| | | |
| | | |
| | |
| Settled commodity derivatives (2) | |
$ | 0.02 | | |
$ | (0.29 | ) | |
$ | (0.05 | ) | |
$ | — | | |
$ | 0.01 | |
| Average realized prices after settled derivatives | |
$ | 2.16 | | |
$ | 59.40 | | |
$ | 34.11 | | |
$ | 7.82 | | |
$ | 2.90 | |
| Premium / (Discount) to NYMEX | |
$ | 0.06 | | |
$ | (14.38 | ) | |
| | | |
| | | |
$ | 0.80 | |
| (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 future 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 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 $0.01 per gallon discount to Mont Belvieu pricing.
| | |
Three Months Ended June 30, 2023 |
| | |
Pricing Point | |
Net C3+ NGL
Production
(Bbl/d) | | |
% by Destination | | |
Premium (Discount)
To Mont Belvieu
($/Gal) | |
| Propane / Butane exported on ME2 | |
Marcus Hook, PA | |
| 60,469 | | |
| 54 | % | |
$ | 0.07 | |
| Remaining C3+ NGL volume | |
Hopedale, OH | |
| 51,344 | | |
| 46 | % | |
$ | (0.10 | ) |
| Total C3+ NGLs/Blended Premium | |
| |
| 111,813 | | |
| 100 | % | |
$ | (0.01 | ) |
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):
| | |
Three Months Ended June 30, | |
| | |
2022 | | |
2023 | |
| Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation | |
$ | 765,135 | | |
| (83,084 | ) |
| Net income and comprehensive income attributable to noncontrolling interests | |
| 46,898 | | |
| 15,151 | |
| Unrealized commodity derivative gains | |
| (293,665 | ) | |
| (4,803 | ) |
| Amortization of deferred revenue, VPP | |
| (9,375 | ) | |
| (7,618 | ) |
| Loss (gain) on sale of assets | |
| 71 | | |
| (220 | ) |
| Impairment of property and equipment | |
| 23,363 | | |
| 15,710 | |
| Equity-based compensation | |
| 8,171 | | |
| 13,512 | |
| Loss on early extinguishment of debt | |
| 4,414 | | |
| — | |
| Equity in earnings of unconsolidated affiliate | |
| (14,713 | ) | |
| (19,098 | ) |
| Contract termination | |
| 2,096 | | |
| 4,441 | |
| Tax effect of reconciling items (1) | |
| 64,914 | | |
| (414 | ) |
| | |
| 597,309 | | |
| (66,423 | ) |
| Martica adjustments (2) | |
| (34,637 | ) | |
| (17,255 | ) |
| Adjusted Net Income (Loss) | |
$ | 562,672 | | |
| (83,678 | ) |
| | |
| | | |
| | |
| Diluted Weighted Average Shares Outstanding (3) | |
| 334,561 | | |
| 300,141 | |
|
(1) |
Deferred taxes were approximately 23% and 21% for 2022 and 2023, 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 income (loss) per share - diluted. Anti-dilutive weighted average shares outstanding for the three months
ended June 30, 2022 and 2023 were 0.4 million and 15.3 million, respectively. |
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):
| | |
December 31, | | |
June 30, | |
| | |
2022 | | |
2023 | |
| Credit Facility | |
$ | 34,800 | | |
| 359,900 | |
| 8.375% senior notes due 2026 | |
| 96,870 | | |
| 96,870 | |
| 7.625% senior notes due 2029 | |
| 407,115 | | |
| 407,115 | |
| 5.375% senior notes due 2030 | |
| 600,000 | | |
| 600,000 | |
| 4.250% convertible senior notes due 2026 | |
| 56,932 | | |
| 39,426 | |
| Unamortized debt issuance costs | |
| (12,241 | ) | |
| (11,041 | ) |
| Total long-term debt | |
$ | 1,183,476 | | |
| 1,492,270 | |
| Less: Cash and cash equivalents | |
| — | | |
| — | |
| Net Debt | |
$ | 1,183,476 | | |
| 1,492,270 | |
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.
| | |
Three Months Ended June 30, | |
| | |
2022 | | |
2023 | |
| Reconciliation of net income (loss) to Adjusted EBITDAX: | |
| | | |
| | |
| Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation | |
$ | 765,135 | | |
| (83,084 | ) |
| Net income and comprehensive income attributable to noncontrolling interests | |
| 46,898 | | |
| 15,151 | |
| Unrealized commodity derivative gains | |
| (293,665 | ) | |
| (4,803 | ) |
| Amortization of deferred revenue, VPP | |
| (9,375 | ) | |
| (7,618 | ) |
| Loss (gain) on sale of assets | |
| 71 | | |
| (220 | ) |
| Interest expense, net | |
| 34,213 | | |
| 27,928 | |
| Loss on early extinguishment of debt | |
| 4,414 | | |
| — | |
| Income tax expense (benefit) | |
| 225,571 | | |
| (29,833 | ) |
| Depletion, depreciation, amortization and accretion | |
| 174,199 | | |
| 172,610 | |
| Impairment of property and equipment | |
| 23,363 | | |
| 15,710 | |
| Exploration expense | |
| 862 | | |
| 743 | |
| Equity-based compensation expense | |
| 8,171 | | |
| 13,512 | |
| Equity in earnings of unconsolidated affiliate | |
| (14,713 | ) | |
| (19,098 | ) |
| Dividends from unconsolidated affiliate | |
| 31,284 | | |
| 31,284 | |
| Contract termination, transaction expense and other | |
| 2,129 | | |
| 4,444 | |
| | |
| 998,557 | | |
| 136,726 | |
| Martica related adjustments (1) | |
| (45,305 | ) | |
| (23,625 | ) |
| Adjusted EBITDAX | |
$ | 953,252 | | |
| 113,101 | |
| | |
| | | |
| | |
| Reconciliation of our Adjusted EBITDAX to net cash provided by operating activities: | |
| | | |
| | |
| Adjusted EBITDAX | |
$ | 953,252 | | |
| 113,101 | |
| Martica related adjustments (1) | |
| 45,305 | | |
| 23,625 | |
| Interest expense, net | |
| (34,213 | ) | |
| (27,928 | ) |
| Amortization of debt issuance costs, debt discount and debt premium | |
| 1,064 | | |
| 861 | |
| Exploration expense | |
| (862 | ) | |
| (743 | ) |
| Changes in current assets and liabilities | |
| (43,224 | ) | |
| 51,144 | |
| Contract termination, transaction expense and other | |
| (2,129 | ) | |
| (4,444 | ) |
| Other items | |
| 3,519 | | |
| (353 | ) |
| Net cash provided by operating activities | |
$ | 922,712 | | |
| 155,263 | |
| (1) | Adjustments reflect noncontrolling interests in Martica not otherwise adjusted in amounts above. |
| | |
Twelve | |
| | |
Months Ended | |
| | |
June 30, | |
| | |
2023 | |
| Reconciliation of net income to Adjusted EBITDAX: | |
| | |
| Net income and comprehensive income attributable to Antero Resources Corporation | |
$ | 1,420,402 | |
| Net income and comprehensive income attributable to noncontrolling interests | |
| 161,502 | |
| Unrealized commodity derivative gains | |
| (1,075,160 | ) |
| Payments for derivative monetizations | |
| 202,339 | |
| Amortization of deferred revenue, VPP | |
| (34,107 | ) |
| Gain on sale of assets | |
| (1,697 | ) |
| Interest expense, net | |
| 107,074 | |
| Loss on early extinguishment of debt | |
| 30,959 | |
| Loss on convertible note inducement | |
| 255 | |
| Income tax expense | |
| 308,563 | |
| Depletion, depreciation, amortization, and accretion | |
| 681,266 | |
| Impairment of property and equipment | |
| 135,176 | |
| Exploration expense | |
| 3,388 | |
| Equity-based compensation expense | |
| 49,153 | |
| Equity in earnings of unconsolidated affiliate | |
| (69,215 | ) |
| Dividends from unconsolidated affiliate | |
| 125,138 | |
| Contract termination, transaction expense and other | |
| 59,973 | |
| | |
| 2,105,009 | |
| Martica related adjustments (1) | |
| (135,332 | ) |
| Adjusted EBITDAX | |
$ | 1,969,677 | |
| (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
June 30, | |
| | |
2022 | | |
2023 | |
| Drilling and completion costs (cash basis) | |
$ | 208,949 | | |
| 244,437 | |
| Change in accrued capital costs | |
| 7,842 | | |
| 2,316 | |
| Adjusted drilling and completion costs (accrual basis) | |
$ | 216,791 | | |
| 246,753 | |
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.
For more information, contact Daniel Katzenberg,
Director - Finance and Investor Relations of Antero Resources at (303) 357-7219 or dkatzenberg@anteroresources.com.
ANTERO RESOURCES CORPORATION
Condensed Consolidated Balance Sheets
(In thousands, except per share amounts)
| | |
| | |
(Unaudited) | |
| | |
December 31, | | |
June 30, | |
| | |
2022 | | |
2023 | |
| Assets |
| Current assets: | |
| | | |
| | |
| Accounts receivable | |
$ | 35,488 | | |
| 36,887 | |
| Accrued revenue | |
| 707,685 | | |
| 323,440 | |
| Derivative instruments | |
| 1,900 | | |
| 3,099 | |
| Prepaid expenses and other current assets | |
| 42,452 | | |
| 21,302 | |
| Total current assets | |
| 787,525 | | |
| 384,728 | |
| Property and equipment: | |
| | | |
| | |
| Oil and gas properties, at cost (successful efforts method): | |
| | | |
| | |
| Unproved properties | |
| 997,715 | | |
| 1,017,828 | |
| Proved properties | |
| 13,234,777 | | |
| 13,615,891 | |
| Gathering systems and facilities | |
| 5,802 | | |
| 5,802 | |
| Other property and equipment | |
| 83,909 | | |
| 91,255 | |
| | |
| 14,322,203 | | |
| 14,730,776 | |
| Less accumulated depletion, depreciation and amortization | |
| (4,683,399 | ) | |
| (4,854,565 | ) |
| Property and equipment, net | |
| 9,638,804 | | |
| 9,876,211 | |
| Operating leases right-of-use assets | |
| 3,444,331 | | |
| 3,262,253 | |
| Derivative instruments | |
| 9,844 | | |
| 7,934 | |
| Investment in unconsolidated affiliate | |
| 220,429 | | |
| 218,196 | |
| Other assets | |
| 17,106 | | |
| 17,488 | |
| Total assets | |
$ | 14,118,039 | | |
| 13,766,810 | |
| Liabilities and Equity |
| Current liabilities: | |
| | | |
| | |
| Accounts payable | |
$ | 77,543 | | |
| 60,911 | |
| Accounts payable, related parties | |
| 80,708 | | |
| 95,360 | |
| Accrued liabilities | |
| 461,788 | | |
| 366,038 | |
| Revenue distributions payable | |
| 468,210 | | |
| 359,487 | |
| Derivative instruments | |
| 97,765 | | |
| 35,509 | |
| Short-term lease liabilities | |
| 556,636 | | |
| 553,953 | |
| Deferred revenue, VPP | |
| 30,552 | | |
| 28,878 | |
| Other current liabilities | |
| 1,707 | | |
| 6,728 | |
| Total current liabilities | |
| 1,774,909 | | |
| 1,506,864 | |
| Long-term liabilities: | |
| | | |
| | |
| Long-term debt | |
| 1,183,476 | | |
| 1,492,270 | |
| Deferred income tax liability, net | |
| 759,861 | | |
| 792,149 | |
| Derivative instruments | |
| 345,280 | | |
| 59,224 | |
| Long-term lease liabilities | |
| 2,889,854 | | |
| 2,711,735 | |
| Deferred revenue, VPP | |
| 87,813 | | |
| 74,337 | |
| Other liabilities | |
| 59,692 | | |
| 61,903 | |
| Total liabilities | |
| 7,100,885 | | |
| 6,698,482 | |
| 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; 297,393 shares issued and 297,359 outstanding as of December 31, 2022, and 300,359 shares issued and outstanding as of June 30, 2023 | |
| 2,974 | | |
| 3,004 | |
| Additional paid-in capital | |
| 5,838,848 | | |
| 5,803,634 | |
| Retained earnings | |
| 913,896 | | |
| 1,019,256 | |
| Treasury stock, at cost; 34 shares and zero shares as of December 31, 2022 and June 30, 2023, respectively | |
| (1,160 | ) | |
| — | |
| Total stockholders' equity | |
| 6,754,558 | | |
| 6,825,894 | |
| Noncontrolling interests | |
| 262,596 | | |
| 242,434 | |
| Total equity | |
| 7,017,154 | | |
| 7,068,328 | |
| Total liabilities and equity | |
$ | 14,118,039 | | |
| 13,766,810 | |
ANTERO RESOURCES CORPORATION
Condensed Consolidated Statements of Operations
and Comprehensive Income (Loss) (Unaudited)
(In thousands, except per share amounts)
| | |
Three Months Ended June 30, | |
| | |
2022 | | |
2023 | |
| Revenue and other: | |
| | | |
| | |
| Natural gas sales | |
$ | 1,558,994 | | |
| 437,130 | |
| Natural gas liquids sales | |
| 702,388 | | |
| 397,733 | |
| Oil sales | |
| 89,185 | | |
| 57,962 | |
| Commodity derivative fair value gains (losses) | |
| (265,662 | ) | |
| 8,284 | |
| Marketing | |
| 106,150 | | |
| 43,793 | |
| Amortization of deferred revenue, VPP | |
| 9,375 | | |
| 7,618 | |
| Other revenue and income | |
| 1,255 | | |
| 785 | |
| Total revenue | |
| 2,201,685 | | |
| 953,305 | |
| Operating expenses: | |
| | | |
| | |
| Lease operating | |
| 25,253 | | |
| 28,748 | |
| Gathering, compression, processing and transportation | |
| 656,212 | | |
| 663,975 | |
| Production and ad valorem taxes | |
| 81,842 | | |
| 36,158 | |
| Marketing | |
| 131,298 | | |
| 66,175 | |
| Exploration and mine expenses | |
| 1,394 | | |
| 743 | |
| General and administrative (including equity-based compensation expense of $8,171 and $13,512 in 2022 and 2023, respectively) | |
| 44,439 | | |
| 53,901 | |
| Depletion, depreciation and amortization | |
| 173,395 | | |
| 171,406 | |
| Impairment of property and equipment | |
| 23,363 | | |
| 15,710 | |
| Accretion of asset retirement obligations | |
| 804 | | |
| 1,204 | |
| Contract termination | |
| 2,096 | | |
| 4,441 | |
| Loss (gain) on sale of assets | |
| 71 | | |
| (220 | ) |
| Total operating expenses | |
| 1,140,167 | | |
| 1,042,241 | |
| Operating income (loss) | |
| 1,061,518 | | |
| (88,936 | ) |
| Other income (expense): | |
| | | |
| | |
| Interest expense, net | |
| (34,213 | ) | |
| (27,928 | ) |
| Equity in earnings of unconsolidated affiliate | |
| 14,713 | | |
| 19,098 | |
| Loss on early extinguishment of debt | |
| (4,414 | ) | |
| — | |
| Total other expense | |
| (23,914 | ) | |
| (8,830 | ) |
| Income (loss) before income taxes | |
| 1,037,604 | | |
| (97,766 | ) |
| Income tax benefit (expense) | |
| (225,571 | ) | |
| 29,833 | |
| Net income (loss) and comprehensive income (loss) including noncontrolling interests | |
| 812,033 | | |
| (67,933 | ) |
| Less: net income and comprehensive income attributable to noncontrolling interests | |
| 46,898 | | |
| 15,151 | |
| Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation | |
$ | 765,135 | | |
| (83,084 | ) |
| | |
| | | |
| | |
| Income (loss) per share—basic | |
$ | 2.46 | | |
| (0.28 | ) |
| Income (loss) per share—diluted | |
$ | 2.29 | | |
| (0.28 | ) |
| | |
| | | |
| | |
| Weighted average number of shares outstanding: | |
| | | |
| | |
| Basic | |
| 310,535 | | |
| 300,141 | |
| Diluted | |
| 334,561 | | |
| 300,141 | |
ANTERO RESOURCES CORPORATION
Condensed Consolidated Statements of Cash Flows
(Unaudited)
(In thousands)
| | |
Six Months Ended June 30, | |
| | |
2022 | | |
2023 | |
| Cash flows provided by (used in) operating activities: | |
| | | |
| | |
| Net income including noncontrolling interests | |
$ | 637,337 | | |
| 193,269 | |
| Adjustments to reconcile net income to net cash provided by operating activities: | |
| | | |
| | |
| Depletion, depreciation, amortization and accretion | |
| 345,031 | | |
| 341,070 | |
| Impairments | |
| 45,825 | | |
| 31,270 | |
| Commodity derivative fair value losses (gains) | |
| 1,277,042 | | |
| (134,476 | ) |
| Losses on settled commodity derivatives | |
| (844,713 | ) | |
| (10,787 | ) |
| Payments for derivative monetizations | |
| — | | |
| (202,339 | ) |
| Deferred income tax expense | |
| 171,707 | | |
| 32,288 | |
| Equity-based compensation expense | |
| 12,820 | | |
| 26,530 | |
| Equity in earnings of unconsolidated affiliate | |
| (39,891 | ) | |
| (36,779 | ) |
| Dividends of earnings from unconsolidated affiliate | |
| 62,569 | | |
| 62,569 | |
| Amortization of deferred revenue | |
| (18,647 | ) | |
| (15,151 | ) |
| Amortization of debt issuance costs, debt discount and debt premium | |
| 2,515 | | |
| 1,732 | |
| Settlement of asset retirement obligations | |
| (886 | ) | |
| (633 | ) |
| Loss (gain) on sale of assets | |
| 1,857 | | |
| (311 | ) |
| Loss on early extinguishment of debt | |
| 15,068 | | |
| — | |
| Loss on convertible note inducement | |
| — | | |
| 86 | |
| Changes in current assets and liabilities: | |
| | | |
| | |
| Accounts receivable | |
| 53,623 | | |
| (1,399 | ) |
| Accrued revenue | |
| (360,612 | ) | |
| 384,245 | |
| Other current assets | |
| (22,566 | ) | |
| 21,294 | |
| Accounts payable including related parties | |
| 50,378 | | |
| 12,701 | |
| Accrued liabilities | |
| 37,203 | | |
| (102,668 | ) |
| Revenue distributions payable | |
| 40,166 | | |
| (108,723 | ) |
| Other current liabilities | |
| 22,559 | | |
| 5,377 | |
| Net cash provided by operating activities | |
| 1,488,385 | | |
| 499,165 | |
| Cash flows provided by (used in) investing activities: | |
| | | |
| | |
| Additions to unproved properties | |
| (72,072 | ) | |
| (110,447 | ) |
| Drilling and completion costs | |
| (393,506 | ) | |
| (517,591 | ) |
| Additions to other property and equipment | |
| (11,162 | ) | |
| (9,058 | ) |
| Proceeds from asset sales | |
| 195 | | |
| 311 | |
| Change in other assets | |
| 1,711 | | |
| (1,255 | ) |
| Net cash used in investing activities | |
| (474,834 | ) | |
| (638,040 | ) |
| Cash flows provided by (used in) financing activities: | |
| | | |
| | |
| Repurchases of common stock | |
| (293,051 | ) | |
| (75,356 | ) |
| Repayment of senior notes | |
| (658,906 | ) | |
| — | |
| Borrowings on bank credit facilities, net | |
| 70,800 | | |
| 325,100 | |
| Convertible note inducement | |
| — | | |
| (86 | ) |
| Distributions to noncontrolling interests in Martica Holdings LLC | |
| (67,298 | ) | |
| (83,084 | ) |
| Employee tax withholding for settlement of equity compensation awards | |
| (64,819 | ) | |
| (27,357 | ) |
| Other | |
| (277 | ) | |
| (342 | ) |
| Net cash provided by (used in) financing activities | |
| (1,013,551 | ) | |
| 138,875 | |
| 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 | |
$ | 89,326 | | |
| 51,927 | |
| Decrease in accounts payable and accrued liabilities for additions to property and equipment | |
$ | (3,504 | ) | |
| (8,353 | ) |
The following table sets forth selected financial data for the three
months ended June 30, 2022 and 2023:
| | |
Three Months Ended | | |
Amount of | | |
| |
| | |
June 30, | | |
Increase | | |
Percent | |
| | |
2022 | | |
2023 | | |
(Decrease) | | |
Change | |
| Revenue: | |
| | |
| | |
| | |
| |
| Natural gas sales | |
$ | 1,558,994 | | |
| 437,130 | | |
| (1,121,864 | ) | |
| (72 | )% |
| Natural gas liquids sales | |
| 702,388 | | |
| 397,733 | | |
| (304,655 | ) | |
| (43 | )% |
| Oil sales | |
| 89,185 | | |
| 57,962 | | |
| (31,223 | ) | |
| (35 | )% |
| Commodity derivative fair value gains (losses) | |
| (265,662 | ) | |
| 8,284 | | |
| 273,946 | | |
| * | |
| Marketing | |
| 106,150 | | |
| 43,793 | | |
| (62,357 | ) | |
| (59 | )% |
| Amortization of deferred revenue, VPP | |
| 9,375 | | |
| 7,618 | | |
| (1,757 | ) | |
| (19 | )% |
| Other revenue and income | |
| 1,255 | | |
| 785 | | |
| (470 | ) | |
| (37 | )% |
| Total revenue | |
| 2,201,685 | | |
| 953,305 | | |
| (1,248,380 | ) | |
| (57 | )% |
| Operating expenses: | |
| | | |
| | | |
| | | |
| | |
| Lease operating | |
| 25,253 | | |
| 28,748 | | |
| 3,495 | | |
| 14 | % |
| Gathering and compression | |
| 223,650 | | |
| 211,691 | | |
| (11,959 | ) | |
| (5 | )% |
| Processing | |
| 219,100 | | |
| 262,642 | | |
| 43,542 | | |
| 20 | % |
| Transportation | |
| 213,462 | | |
| 189,642 | | |
| (23,820 | ) | |
| (11 | )% |
| Production and ad valorem taxes | |
| 81,842 | | |
| 36,158 | | |
| (45,684 | ) | |
| (56 | )% |
| Marketing | |
| 131,298 | | |
| 66,175 | | |
| (65,123 | ) | |
| (50 | )% |
| Exploration and mine expenses | |
| 1,394 | | |
| 743 | | |
| (651 | ) | |
| (47 | )% |
| General and administrative (excluding equity-based compensation) | |
| 36,268 | | |
| 40,389 | | |
| 4,121 | | |
| 11 | % |
| Equity-based compensation | |
| 8,171 | | |
| 13,512 | | |
| 5,341 | | |
| 65 | % |
| Depletion, depreciation and amortization | |
| 173,395 | | |
| 171,406 | | |
| (1,989 | ) | |
| (1 | )% |
| Impairment of property and equipment | |
| 23,363 | | |
| 15,710 | | |
| (7,653 | ) | |
| (33 | )% |
| Accretion of asset retirement obligations | |
| 804 | | |
| 1,204 | | |
| 400 | | |
| 50 | % |
| Contract termination | |
| 2,096 | | |
| 4,441 | | |
| 2,345 | | |
| 112 | % |
| Loss (gain) on sale of assets | |
| 71 | | |
| (220 | ) | |
| (291 | ) | |
| * | |
| Total operating expenses | |
| 1,140,167 | | |
| 1,042,241 | | |
| (97,926 | ) | |
| (9 | )% |
| Operating income (loss) | |
| 1,061,518 | | |
| (88,936 | ) | |
| (1,150,454 | ) | |
| * | |
| Other earnings (expenses): | |
| | | |
| | | |
| | | |
| | |
| Interest expense, net | |
| (34,213 | ) | |
| (27,928 | ) | |
| 6,285 | | |
| (18 | )% |
| Equity in earnings of unconsolidated affiliate | |
| 14,713 | | |
| 19,098 | | |
| 4,385 | | |
| 30 | % |
| Loss on early extinguishment of debt | |
| (4,414 | ) | |
| — | | |
| 4,414 | | |
| * | |
| Total other expense | |
| (23,914 | ) | |
| (8,830 | ) | |
| 15,084 | | |
| (63 | )% |
| Income (loss) before income taxes | |
| 1,037,604 | | |
| (97,766 | ) | |
| (1,135,370 | ) | |
| * | |
| Income tax benefit (expense) | |
| (225,571 | ) | |
| 29,833 | | |
| 255,404 | | |
| * | |
| Net income (loss) and comprehensive income (loss) including noncontrolling interests | |
| 812,033 | | |
| (67,933 | ) | |
| (879,966 | ) | |
| * | |
| Less: net income and comprehensive income attributable to noncontrolling interests | |
| 46,898 | | |
| 15,151 | | |
| (31,747 | ) | |
| (68 | )% |
| Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation | |
$ | 765,135 | | |
| (83,084 | ) | |
| (848,219 | ) | |
| * | |
| | |
| | | |
| | | |
| | | |
| | |
| Adjusted EBITDAX | |
$ | 953,252 | | |
| 113,101 | | |
| (840,151 | ) | |
| (88 | )% |
* Not meaningful
The following table sets forth selected financial data for the three
months ended June 30, 2022 and 2023:
| | |
Three Months Ended | | |
Amount of | | |
| |
| | |
June 30, | | |
Increase | | |
Percent | |
| | |
2022 | | |
2023 | | |
(Decrease) | | |
Change | |
| Production data (1) (2): | |
| | | |
| | | |
| | | |
| | |
| Natural gas (Bcf) | |
| 203 | | |
| 204 | | |
| 1 | | |
| * | |
| C2 Ethane (MBbl) | |
| 4,025 | | |
| 6,414 | | |
| 2,389 | | |
| 59 | % |
| C3+ NGLs (MBbl) | |
| 10,156 | | |
| 10,175 | | |
| 19 | | |
| * | |
| Oil (MBbl) | |
| 906 | | |
| 971 | | |
| 65 | | |
| 7 | % |
| Combined (Bcfe) | |
| 294 | | |
| 309 | | |
| 15 | | |
| 5 | % |
| Daily combined production (MMcfe/d) | |
| 3,228 | | |
| 3,400 | | |
| 172 | | |
| 5 | % |
| Average prices before effects of derivative settlements (3): | |
| | | |
| | | |
| | | |
| | |
| Natural gas (per Mcf) | |
$ | 7.67 | | |
| 2.14 | | |
| (5.53 | ) | |
| (72 | )% |
| C2 Ethane (per Bbl) (4) | |
$ | 22.42 | | |
| 7.82 | | |
| (14.60 | ) | |
| (65 | )% |
| C3+ NGLs (per Bbl) | |
$ | 60.28 | | |
| 34.16 | | |
| (26.12 | ) | |
| (43 | )% |
| Oil (per Bbl) | |
$ | 98.49 | | |
| 59.69 | | |
| (38.80 | ) | |
| (39 | )% |
| Weighted Average Combined (per Mcfe) | |
$ | 8.00 | | |
| 2.89 | | |
| (5.11 | ) | |
| (64 | )% |
| Average realized prices after effects of derivative settlements (3): | |
| | | |
| | | |
| | | |
| | |
| Natural gas (per Mcf) | |
$ | 4.94 | | |
| 2.16 | | |
| (2.78 | ) | |
| (56 | )% |
| C2 Ethane (per Bbl) (4) | |
$ | 22.42 | | |
| 7.82 | | |
| (14.60 | ) | |
| (65 | )% |
| C3+ NGLs (per Bbl) | |
$ | 59.84 | | |
| 34.11 | | |
| (25.73 | ) | |
| (43 | )% |
| Oil (per Bbl) | |
$ | 97.73 | | |
| 59.40 | | |
| (38.33 | ) | |
| (39 | )% |
| Weighted Average Combined (per Mcfe) | |
$ | 6.10 | | |
| 2.90 | | |
| (3.20 | ) | |
| (52 | )% |
| Average costs (per Mcfe): | |
| | | |
| | | |
| | | |
| | |
| Lease operating | |
$ | 0.09 | | |
| 0.09 | | |
| — | | |
| * | |
| Gathering and compression | |
$ | 0.76 | | |
| 0.68 | | |
| (0.08 | ) | |
| (11 | )% |
| Processing | |
$ | 0.75 | | |
| 0.85 | | |
| 0.10 | | |
| 13 | % |
| Transportation | |
$ | 0.73 | | |
| 0.61 | | |
| (0.12 | ) | |
| (16 | )% |
| Production and ad valorem taxes | |
$ | 0.28 | | |
| 0.12 | | |
| (0.16 | ) | |
| (57 | )% |
| Marketing expense, net | |
$ | 0.09 | | |
| 0.07 | | |
| (0.02 | ) | |
| (22 | )% |
| General and administrative (excluding equity-based compensation) | |
$ | 0.12 | | |
| 0.13 | | |
| 0.01 | | |
| 8 | % |
| Depletion, depreciation, amortization and accretion | |
$ | 0.59 | | |
| 0.56 | | |
| (0.03 | ) | |
| (5 | )% |
| (1) | Production data excludes volumes related to the VPP. |
| (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. |
| (4) | The average realized price for the three months ended June 30, 2023 includes $6 million of proceeds related to a take-or-pay
contract. Excluding the effect of these proceeds, the average realized price for ethane before and after the effects of derivatives would
have been $7.65 per Bbl. |
v3.23.2
| X |
- DefinitionBoolean flag that is true when the XBRL content amends previously-filed or accepted submission.
| Name: |
dei_AmendmentFlag |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionFor the EDGAR submission types of Form 8-K: the date of the report, the date of the earliest event reported; for the EDGAR submission types of Form N-1A: the filing date; for all other submission types: the end of the reporting or transition period. The format of the date is YYYY-MM-DD.
| Name: |
dei_DocumentPeriodEndDate |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:dateItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe type of document being provided (such as 10-K, 10-Q, 485BPOS, etc). The document type is limited to the same value as the supporting SEC submission type, or the word 'Other'.
| Name: |
dei_DocumentType |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:submissionTypeItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionAddress Line 1 such as Attn, Building Name, Street Name
| Name: |
dei_EntityAddressAddressLine1 |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- Definition
+ References
+ Details
| Name: |
dei_EntityAddressCityOrTown |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionCode for the postal or zip code
| Name: |
dei_EntityAddressPostalZipCode |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionName of the state or province.
| Name: |
dei_EntityAddressStateOrProvince |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:stateOrProvinceItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionA unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityCentralIndexKey |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:centralIndexKeyItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionIndicate if registrant meets the emerging growth company criteria. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityEmergingGrowthCompany |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionCommission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.
| Name: |
dei_EntityFileNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:fileNumberItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTwo-character EDGAR code representing the state or country of incorporation.
| Name: |
dei_EntityIncorporationStateCountryCode |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarStateCountryItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityRegistrantName |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityTaxIdentificationNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:employerIdItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionLocal phone number for entity.
| Name: |
dei_LocalPhoneNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 13e
-Subsection 4c
| Name: |
dei_PreCommencementIssuerTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 14d
-Subsection 2b
| Name: |
dei_PreCommencementTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTitle of a 12(b) registered security. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b
| Name: |
dei_Security12bTitle |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:securityTitleItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionName of the Exchange on which a security is registered. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection d1-1
| Name: |
dei_SecurityExchangeName |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarExchangeCodeItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Section 14a
-Number 240
-Subsection 12
| Name: |
dei_SolicitingMaterial |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTrading symbol of an instrument as listed on an exchange.
| Name: |
dei_TradingSymbol |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:tradingSymbolItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Securities Act
-Number 230
-Section 425
| Name: |
dei_WrittenCommunications |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
Antero Resources (NYSE:AR)
Historical Stock Chart
From Dec 2024 to Jan 2025
Antero Resources (NYSE:AR)
Historical Stock Chart
From Jan 2024 to Jan 2025
