DENVER, Feb. 12, 2020 /PRNewswire/ -- Antero
Resources Corporation (NYSE: AR) ("Antero Resources" or the
"Company") today announced its fourth quarter and full year 2019
financial and operational results as well as its 2020 capital
budget, guidance and proved reserves as of December 31, 2019. The relevant
consolidated financial statements are included in Antero Resource's
Annual Report on Form 10-K for the year ended December 31, 2019.
Fourth Quarter and Full Year 2019 Highlights Include:
- Net production averaged 3,185 MMcfe/d (30% liquids by
volume) during the fourth quarter and 3,220 MMcfe/d for the full
year, a 19% year-over-year increase compared to 2018
- Realized natural gas equivalent price averaged $3.18 per Mcfe during the quarter
-
- Includes pre-hedge C3+ NGL price of $29.61/Bbl
- All-in cash expenses were $2.34 per Mcfe during the quarter, a $0.22, or 8% reduction from the first half of
2019
-
- Net marketing expense was $0.17 per Mcfe during the quarter, a $0.05 or 23% decrease from the prior
quarter
- Drilling and completion capital spending was $300 million during the fourth quarter and
$1.27 billion for the full year, an
11% and 14% decrease, respectively, compared to the prior year
periods
- Proved reserves increased 5% to 18.9 Tcfe at year-end 2019
compared to year-end 2018 and proved developed reserves increased
13% to 11.7 Tcfe
- Future development cost estimate for 7.2 Tcfe of proved
undeveloped reserves is $0.37 per
Mcfe
2020 Guidance Highlights:
- Drilling and completion capital budget of
$1.15 billion, down 10% from
2019
- Full year 2020 net production is expected to average 3,500
MMcfe/d, a 9% increase over 2019 net production
-
- Liquids production, including oil, C3+ NGLs, and ethane
assuming 25% recovery, is expected to average 187,500
Bbl/d
- All-in cash expenses, including net marketing expense, are
expected to be $2.25 to $2.35 per Mcfe, an $0.18 decrease from 2019
-
- Net marketing expense is forecast to be $0.10 to $0.12 per
Mcfe, an $0.11 decline from
2019
- Natural gas production guidance is 94% hedged at
$2.87/MMBtu
- Estimated oil and oil-equivalent production of 26,000 Bbl/d
(pentanes are hedged to WTI) is 100% hedged in 2020 at $55.63/Bbl
Paul Rady, Chairman and Chief
Executive Officer of Antero Resources commented, "Our 2020 capital
budget highlights the direct benefit from our well cost savings
initiatives that we launched in 2019. In simple terms, we
have reduced our total well cost per foot from $970 in the initial 2019 budget to a target of
$795 to $825 per for 2020. The result is a 10%
reduction in drilling and completion capital and a 28% reduction in
lease operating expense as compared to 2019, while delivering
production growth of 9%. This level of production in turn
should trigger $75 million in
previously announced gathering, processing and transportation
expense savings in 2020 and paves the way for up to $350 million in total savings between 2020 and
2023. Additionally, by growing into our unutilized firm
transportation commitments we reduce our cost structure by another
$200 million by 2022."
Mr. Rady continued, "We believe that our industry-leading hedge
portfolio and diversified production mix, combined with our ability
to export more than 50% of our C3+ NGL production to premium
international markets, provides Antero with a competitive advantage
throughout commodity price cycles. Our cost savings
initiatives and liquids exposure result in a projected cash flow
neutral profile for 2020 at current strip pricing including the
$125 million water earnout payment
received in January from Antero Midstream."
2020 Capital Budget and Guidance
The following is a summary of Antero Resources' 2020 capital
budget. The capital budget is based on commodity strip
pricing as of February 7, 2020 that
was $52 per barrel WTI oil,
$25 per barrel C3+ NGL and
$2.08 per MMBtu NYMEX natural gas for
2020.
Capital Budget ($
in Billions)
|
|
|
|
|
|
Drilling &
Completion
|
|
|
$1.15
|
|
Land
|
|
|
$0.05
|
|
Total E&P Capital
|
|
|
$1.2
|
|
The following is a summary of Antero Resources' 2020 production,
pricing and cash expense guidance.
Production
Guidance
|
|
|
|
|
Net Daily Natural Gas
Equivalent Production (MMcfe/d)
|
|
|
3,500
|
Net Daily Natural Gas
Production (MMcf/d)
|
|
|
2,375
|
Total Net Daily
Liquids Production (Bbl/d):
|
|
|
187,500
|
|
|
|
Realized Pricing
Guidance
|
|
|
|
|
Natural Gas Realized
Price vs. NYMEX Henry Hub ($/Mcf)
|
|
$0.00 –
$0.10
|
Oil Realized Price
vs. WTI Oil ($/Bbl)
|
|
($7.00) –
($9.00)
|
C3+ NGL Realized
Price vs. Mont Belvieu ($/Gal)
|
|
$0.00 –
$0.05
|
|
|
|
|
Cash Expense
Guidance
|
|
|
Low
|
|
High
|
Cash Production
Expense ($/Mcfe)(1)
|
|
|
$2.07
|
|
$2.13
|
Marketing Expense,
Net of Marketing Revenue ($/Mcfe)
|
|
|
$0.10
|
|
$0.12
|
G&A Expense
($/Mcfe)(2)
|
|
|
$0.08
|
|
$0.10
|
All-In Cash
Expense
|
|
|
$2.25
|
|
$2.35
|
|
(1)
|
Includes lease
operating expenses, gathering, compression, processing and
transportation expenses ("GP&T") and production and ad valorem
taxes.
|
(2)
|
Excludes equity-based
compensation.
|
Well Cost Savings
Antero's drilling and completion capital budget is based on
average total well cost of $825 per
foot, which is at the high end of the 2020 target range of
$795 to $825 per foot. Well costs averaged
$860 per foot in the fourth quarter
of 2019 with only a portion of the wells being completed with
reduced water. The reduction in 2020 well costs is expected
to be driven by both drier completions (36 Bbl of water per foot of
lateral) on all wells and expanded produced water services provided
by Antero Midstream.
Fourth Quarter 2019 Financial Results
For the three months ended December 31,
2019, Antero reported a GAAP net loss of $482 million, or $1.61 per diluted share, compared to a GAAP net
loss of $122 million, or $0.39 per diluted share, in the prior year
period. Adjusted Net Loss (non-GAAP measure) was $6 million, or $0.02 per diluted share, compared to Adjusted Net
Income of $175 million during the
three months ended December 31, 2018, or $0.56 per diluted share. The Adjusted Net
Loss reflects a $468 million
impairment based on the fair value of our equity interest in Antero
Midstream at year end 2019.
Adjusted EBITDAX (non-GAAP measure) was $295 million, a 38% decrease compared to
$475 million in the prior year period
due to lower commodity pricing. Antero's average realized
price after hedges declined 20% from $3.97 per Mcfe in the fourth quarter of 2018 to
$3.18 per Mcfe in the fourth quarter
of 2019.
The following table details the components of average net
production and average realized prices for the three months ended
December 31, 2019:
|
|
Three months ended
December 31, 2019
|
|
|
Natural Gas
(MMcf/d)
|
|
Oil
(Bbl/d)
|
|
C3+ NGLs
(Bbl/d)
|
|
Ethane
(Bbl/d)
|
|
Combined
Natural Gas
Equivalent
(MMcfe/d)
|
Average Net
Production
|
|
|
2,223
|
|
|
8,793
|
|
|
104,376
|
|
|
47,014
|
|
|
3,185
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Realized
Prices
|
|
Natural Gas
($/Mcf)
|
|
Oil
($/Bbl)
|
|
C3+ NGLs
($/Bbl)
|
|
Ethane
($/Bbl)
|
|
Combined
Natural Gas
Equivalent
($/Mcfe)
|
Average realized
prices before settled derivatives
|
|
$
|
2.50
|
|
$
|
49.29
|
|
$
|
29.61
|
|
$
|
7.44
|
|
$
|
2.96
|
Settled commodity
derivatives
|
|
|
0.37
|
|
|
4.28
|
|
|
(1.66)
|
|
|
—
|
|
|
0.22
|
Average realized
prices after settled derivatives
|
|
$
|
2.87
|
|
$
|
53.57
|
|
$
|
27.95
|
|
$
|
7.44
|
|
$
|
3.18
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NYMEX average
price
|
|
$
|
2.50
|
|
$
|
56.96
|
|
|
|
|
|
|
|
$
|
2.50
|
Premium /
(Differential) to NYMEX
|
|
$
|
0.37
|
|
$
|
(3.39)
|
|
|
|
|
|
|
|
$
|
0.68
|
Net daily natural gas equivalent production in the fourth
quarter averaged 3,185 MMcfe/d, including 160,183 Bbl/d of liquids
(30% liquids by volume). Liquids revenue represented
approximately 41% of total product revenue before hedges.
Production declined 1% from the prior year period due to the timing
of well completions in 2019 as two pads, totaling 13 wells, were
turned to sales in late December of 2019.
Antero's average realized C3+ NGL price before hedging was
$29.61 per barrel, representing a 4%
decrease versus the prior year period and a 31% increase from the
third quarter of 2019. Antero shipped 41% of its total C3+
NGL net production on Mariner East 2 for export and realized a
$0.21 per gallon premium to Mont
Belvieu pricing on these volumes at Marcus Hook, PA. Antero
sold the remaining 59% of C3+ NGL net production at a $0.09 per gallon discount to Mont Belvieu pricing
at Hopedale, OH. The resulting blended price on 104,376 Bbl/d
of net C3+ NGL production was $29.61
per barrel, which was a $0.03 per
gallon premium to Mont Belvieu pricing. Based on current
strip prices at Mont Belvieu and in the international markets,
Antero expects its realized C3+ NGL prices in 2020 to be
$0.00 to a $0.05 per gallon premium to Mont Belvieu.
Antero expects to sell at least 50% of its C3+ NGL production
in 2020 at Marcus Hook for export at a premium to Mont
Belvieu.
|
Three months ended
December 31, 2019
|
|
|
Pricing
Point
|
|
Net C3+
NGL
Production
(Bbl/d)
|
|
% by
Destination
|
|
Premium
(Discount)
To Mont
Belvieu
($/Gal)
|
Propane / Butane
shipped on ME2
|
Marcus
Hook
|
|
42,794
|
|
41%
|
|
$0.21
|
Remaining C3+ NGL
volume
|
Hopedale
|
|
61,582
|
|
59%
|
|
($0.09)
|
Total C3+
NGLs
|
|
|
|
104,376
|
|
100%
|
|
$0.03
|
Cash Expense and Net Marketing Expense
All-in per unit cash expense, which includes lease operating,
GP&T, production and ad valorem taxes, net marketing and
general and administrative expense (excluding equity-based
compensation) was $2.34 per Mcfe in
the fourth quarter, an 8% decrease compared to $2.56 per Mcfe average during the first half of
2019. Antero expects all-in cash expense of $2.25 to $2.35 per
Mcfe as a result of the recently announced midstream fee
reductions, filling unutilized firm transportation, and ongoing
progress on the water savings initiatives that reduces lease
operating expense.
Per unit net marketing expense declined to $0.17 per Mcfe in the fourth quarter compared to
$0.22 per Mcfe reported in the prior
year period. The decline was driven by the mitigation of some
of our excess firm transportation expense. Net marketing
expense is expected to decline further in 2020, to $0.10 to $0.12 per
Mcfe, as a result of both an increase in natural gas production
filling excess firm transportation capacity and renegotiated
agreements with midstream providers that allow for higher
utilization of our transportation capacity to the more attractive
pricing in the Gulf Coast markets.
Adjusted EBITDAX margin (non-GAAP measure) was $1.01 per Mcfe, a 37% decrease from the prior
year period, due to lower realized prices relative to the prior
year period. The following table presents a calculation of
Adjusted EBITDAX margin on a per Mcfe basis and a reconciliation to
the realized price before cash receipts for settled derivatives,
the nearest GAAP financial measure. Adjusted EBITDAX margin
represents Adjusted EBITDAX divided by production, and is a measure
that helps investors to more meaningfully evaluate and compare the
results of Antero's operations on a per unit basis from period to
period by removing the effect of its capital structure from its
operating structure.
|
|
|
|
|
|
|
|
|
|
Three months ended
December 31,
|
|
|
|
2018
|
|
2019
|
|
Adjusted EBITDAX
margin ($ per Mcfe):
|
|
|
|
|
|
|
|
Realized price before
cash receipts for settled derivatives
|
|
$
|
4.05
|
|
$
|
2.96
|
|
Distributions/dividends from Antero
Midstream
|
|
|
0.16
|
|
|
0.17
|
|
Marketing,
net
|
|
|
(0.22)
|
|
|
(0.17)
|
|
Gathering,
compression, processing and transportation costs
|
|
|
(1.88)
|
|
|
(1.88)
|
|
Lease operating
expense
|
|
|
(0.15)
|
|
|
(0.09)
|
|
Production and ad
valorem taxes
|
|
|
(0.15)
|
|
|
(0.10)
|
|
General and
administrative (excluding equity-based compensation)
|
|
|
(0.11)
|
|
|
(0.10)
|
|
Adjusted EBITDAX
margin before settled commodity derivatives
|
|
|
1.70
|
|
|
0.79
|
|
Cash receipts for
settled commodity derivatives
|
|
|
(0.09)
|
|
|
0.22
|
|
Adjusted EBITDAX
margin ($ per Mcfe):
|
|
$
|
1.61
|
|
$
|
1.01
|
|
Fourth Quarter 2019 Operating Update
Marcellus Shale — Antero placed 21 horizontal
Marcellus wells to sales during the fourth quarter of 2019 with an
average lateral length of 11,600 feet. For new wells that had
60 days of reported production data during the quarter, the average
60-day rate per well was 18.2 MMcfe/d on choke. The 60-day average
rate per well included 742 Bbl/d of liquids, comprised of oil, C3+
NGLs and assumes 25% ethane recovery.
Additionally, Antero drilled an average of 7,000 lateral feet
per day in the quarter, achieving its highest quarterly rate in the
Company's history. This drilling record represents a 17%
sequential increase and a 38% increase compared to the 2018 average
in lateral footage performance. Antero also drilled a company
one-well record of 10,453 lateral feet in a 24-hour period.
During 2019, Antero drilled 97 wells that averaged over one mile
per day drilling in the lateral and was the only known operator in
the Marcellus to drill over 10,000 lateral feet in a 24-hour
period, which Antero accomplished twice. Antero's ongoing
emphasis on completion efficiencies resulted in an improvement
during the fourth quarter, as the Company averaged 6.3 stages
completed per day, representing a 7% increase from 5.9 stages per
day in the prior period.
Fourth Quarter and Full Year 2019 Capital Investment
Antero's accrued drilling and completion capital expenditures
for the three months ended December 31, 2019 were $300 million. For the full year 2019,
drilling and completion capital expenditures were $1.27 billion, a decrease of 16% from 2018 and 7%
below Antero's original 2019 guidance.
Balance Sheet and Liquidity
As of December 31, 2019, Antero's
total debt was $3.76 billion, of
which $552 million were borrowings
outstanding under the Company's revolving credit facility.
Antero has a borrowing base of $4.5
billion with lender commitments that total $2.64 billion. After deducting letters of
credit outstanding of $623 million,
the Company had $1.5 billion in
available liquidity. The decrease in Antero's outstanding
letters of credit from the prior period reflect new surety bonds
that were secured during the fourth quarter. As of
December 31, 2019, Antero's net debt
to trailing twelve months Adjusted EBITDAX ratio was 3.0x.
Antero repurchased $225 million
principal amount of senior unsecured notes during the fourth
quarter at a 17% weighted average discount price, including both
its 2021 and 2022 senior notes. The repurchases reduced
Antero's total debt by $37 million
and net interest expense was reduced by $6
million on an annualized basis. Antero also repurchased 8.3
million shares of common stock during the fourth quarter at a
weighted average price of $2.50 per
share.
President and CFO, Glen Warren,
commented, "Our ability to materially reduce operating costs and
lower capital spending allows us to protect our balance sheet while
executing a moderate near-term growth strategy to fill our
remaining unfilled premium firm transportation and realize the
midstream fee reductions announced in December. Pro forma for
the recently announced asset sale program, we are targeting a mid
2-times leverage ratio with robust liquidity of $2.3 billion at year-end 2020 excluding further
senior note repurchases or redemptions. Longer term, we are
committed to reducing absolute debt and maximizing free cash flow
as we expect to fill our premium firm transportation commitments by
the end of 2021."
Year End Proved Reserves
At December 31, 2019, Antero's
estimated proved reserves were 18.9 Tcfe, a 5% increase over the
prior year. Estimated proved reserves were comprised of 61%
natural gas, 38% NGLs and 1% oil. The Marcellus Shale
accounted for 92% of estimated proved reserves and the Ohio Utica
Shale accounted for 8%. For 2019, Antero added 3.7 Tcfe of
estimated proved reserves. Approximately 2.3 Tcfe was removed
from Antero's proved reserves due to the SEC 5-year rule, primarily
related to changes in drilling locations in our 5-year development
plan.
Estimated proved developed reserves were 11.7 Tcfe, a 13%
increase over the prior year. The percentage of estimated
proved reserves classified as proved developed increased to 62% at
year-end 2019, compared to 58% at year-end 2018. Antero's 328
proved undeveloped locations average an estimated 1258 BTU, with an
average lateral length of approximately 12,500 feet.
Antero's 7.2 Tcfe of estimated proved undeveloped reserves will
require an estimated $2.6 billion of
future development capital over the next five years, resulting in
an estimated average future development cost for proved undeveloped
reserves of $0.37 per Mcfe.
The following table presents a summary of changes in estimated
proved reserves (in Tcfe).
Proved reserves,
December 31, 2018
|
|
18.0
|
Extensions,
discoveries, and other additions
|
|
3.7
|
Revisions to prior
estimates
|
|
(1.6)
|
Estimated
Production
|
|
(1.2)
|
Proved reserves,
December 31, 2019
|
|
18.9
|
The following table summarizes pre-tax estimated proved reserves
PV-10 (non-GAAP measure) and the associated Standardized
Measure. The decrease in pre-tax estimated proved reserves
PV-10 value as compared to 2018, was due primarily to lower SEC
pricing and the deconsolidation of Antero Resources' and Antero
Midstream's financial statements. Lower pricing resulted in
approximately 65% of the decline and the deconsolidation resulted
in approximately 35% of the reduction. The deconsolidation
resulted in Antero Resources recording the full fees paid to Antero
Midstream for services rendered and no longer recording the future
capital expenditures associated with Antero Midstream assets in
future development costs. Prior to deconsolidation, as required by
SEC guidance, Antero Resources' consolidated reserves included the
elimination of full fees paid by Antero Resources to Antero
Midstream and the inclusion of the operating costs and capital
incurred by Antero Midstream. Detailed SEC pricing can be
found in Antero's Form 10-K for the year ended December 31, 2019.
|
|
|
|
|
|
|
|
|
SEC
Pricing
|
|
|
|
|
Proved Reserve
Value ($B):
|
2019
Year-End
|
|
2018
Year-End
|
|
|
|
%
|
|
(Deconsolidated)
|
|
(Consolidated)
|
|
Variance
|
|
Variance
|
Standardized
Measure
|
$5.5
|
|
$10.5
|
|
$5.0
|
|
-52%
|
Pre-tax estimated
proved reserves PV-10
|
$6.1
|
|
$12.6
|
|
$6.5
|
|
-52%
|
Pre-tax estimated
proved developed reserves PV-10
|
$4.7
|
|
$8.4
|
|
$3.7
|
|
-45%
|
Commodity Derivative Positions
Antero has hedged 1.8 Tcf of natural gas at a weighted average
index price of $2.84 per MMBtu
through 2023 with fixed price swap positions. Antero also has
oil and NGL fixed price swap positions, including NGL positions
that totaled 35,800 Bbl/day and oil positions that totaled 10,000
Bbl/d during 2020. As of December 31,
2019, the Company's estimated fair value of commodity
derivative instruments was $1.1
billion based on strip pricing.
Please see Antero's Annual Report on Form 10-K for the year
ended December 31, 2019, for more information on all commodity
derivative positions.
The following tables summarize Antero's hedge position as of
December 31, 2019:
Fixed price natural gas positions from January 1, 2020 through December 31, 2023 were as follows:
|
|
Natural
gas
MMBtu/day
|
|
Weighted
average
index
price
|
Year ending
December 31, 2020:
|
|
|
|
|
|
NYMEX
($/MMBtu)
|
|
2,227,500
|
|
$
|
2.87
|
Year ending
December 31, 2021:
|
|
|
|
|
|
NYMEX
($/MMBtu)
|
|
2,400,000
|
|
$
|
2.80
|
Year ending
December 31, 2022:
|
|
|
|
|
|
NYMEX
($/MMBtu)
|
|
0
|
|
$
|
N/A
|
Year ending
December 31, 2023:
|
|
|
|
|
|
NYMEX
($/MMBtu)
|
|
90,000
|
|
$
|
2.91
|
C3+ NGL and Oil derivative contract positions from January 1, 2020 through December 31, 2020 were as follows:
|
Derivative Contract
Type
|
Liquids Hedges
(Bbl/d)
|
|
Weighted
average
index price
($/Gal)
|
Weighted
average basis
differential
$/Gal
|
Weighted
average index
price ($/Bbl)
|
Year ending
December 31, 2020:
|
|
|
|
|
|
|
Propane (C3) – Mont
Belvieu (Domestic)
|
Fixed swap
|
373
|
|
$0.50
|
|
$21.00
|
Propane (C3) – ARA
(Europe) (1)
|
Fixed swap
|
10,371
|
|
$0.55
|
|
$23.10
|
Propane (C3) – FEI
(Asia) (1)
|
Fixed swap
|
2,457
|
|
$0.61
|
|
$25.62
|
Normal Butane (C4) –
ARA to Mont Belvieu Basis
|
Basis
|
1,072
|
|
—
|
$0.23
|
—
|
Normal Butane (C4) –
Mont Belvieu (Domestic)
|
Fixed swap
|
1,492
|
|
$0.57
|
|
$24.12
|
Pentane (C5) – Mont
Belvieu (Domestic) (2)
|
Fixed swap
|
20,000
|
|
$1.06
|
|
$44.52
|
Total C3+
NGLs
|
|
35,765
|
|
|
|
|
|
|
|
|
|
|
|
Total NYMEX Crude
Oil
|
|
10,000
|
|
|
|
$55.63
|
|
(1)
|
Net of shipping.
Assumes $0.10/gal shipping to ARA and $0.20/gal shipping to
FEI.
|
|
(2)
|
Hedged 20,000 Bbl/d
of pentane (C5) at 80% of WTI and hedged the resulting 16,000 Bbl/d
of oil-equivalent volumes at $55.63/Bbl WTI or average (80% x
$55.63 = $44.52/Bbl pentane).
|
Conference Call
A conference call is scheduled on Thursday, February 13, 2020 at 9:00 am MT to discuss the financial and
operational results. A brief Q&A session for security
analysts will immediately follow the discussion of the results for
the quarter. To participate in the call, dial in at
877-407-9079 (U.S.), or 201-493-6746 (International) and reference
"Antero Resources". A telephone replay of the call will be
available until Thursday, February 20,
2020 at 9:00 am MT at
877-660-6853 (U.S.) or 201-612-7415 (International) using the
conference ID: 13693463.
A simultaneous webcast of the call may be accessed over the
internet at www.anteroresources.com. The webcast will be
archived for replay on the Company's website until Thursday, February 20, 2020 at 9:00 am MT.
Presentation
An updated presentation will be posted to the Company's website
before the conference call. The presentation can be found at
www.anteroresources.com on the homepage. Information on the
Company's website does not constitute a portion of, and is not
incorporated by reference into, this press release.
Basis of Financial Presentation
In connection with the closing of the simplification transaction
between Antero Midstream GP LP and Antero Midstream Partners LP
("Antero Midstream Partners") on March 12,
2019, among other things, Antero Midstream GP LP converted
to a Delaware corporation and
changed its name to Antero Midstream Corporation ("Antero
Midstream") and Antero Midstream Partners became Antero Midstream's
wholly owned subsidiary. As of December 31, 2019, Antero
Resources owned 29% of the shares of common stock of Antero
Midstream. Through March 12,
2019, Antero Midstream Partners' results were consolidated
within Antero Resources' results. Upon closing, Antero
Midstream Partners was deconsolidated from Antero Resources and
Antero Resources' interests in Antero Midstream were accounted for
under the equity method of accounting within Antero Resources'
results. The GAAP results discussed below include the results
of Antero Midstream Partners from January 1,
2019, through March 12, 2019,
on a consolidated basis, and from March 13,
2019, to December 31, 2019,
the results of Antero Midstream Partners are no longer
consolidated. The non-GAAP results described herein reflect the
applicable results as if the simplification transaction had
occurred at the beginning of the applicable period, unless
otherwise noted.
Non-GAAP Financial Measures
Adjusted Net Income (Loss)
Adjusted Net Income (Loss) as set forth in this release
represents net income (Loss), adjusted for certain items.
Antero believes that Adjusted Net Income (Loss) and Adjusted Net
Income (Loss) per share is useful to investors in evaluating
operational trends of the Company and its performance relative to
other oil and gas producing companies. Adjusted Net Income
(Loss) is not a measure of financial performance under GAAP and
should not be considered in isolation or as a substitute for net
income (Loss) as an indicator of financial performance. The
following tables reconcile net income (loss) before income taxes to
Adjusted Net Income (Loss) (in thousands):
|
Three months
ended
|
|
Twelve months
ended
|
|
December 31,
|
|
December 31,
|
|
2018
|
|
2019
|
|
2018
|
|
2019
|
|
|
|
|
|
|
|
|
|
|
Net loss attributable
to Antero Resources Corp
|
$
|
(121,546)
|
|
$
|
(482,196)
|
$
|
(397,517)
|
|
(340,129)
|
Commodity derivative
fair value losses (gains)
|
|
222,387
|
|
|
7,875
|
|
87,594
|
|
(463,972)
|
Gains (losses) on
settled commodity derivatives
|
|
(25,257)
|
|
|
63,296
|
|
243,112
|
|
325,090
|
Marketing derivative
fair value losses (gains)
|
|
—
|
|
|
—
|
|
(94,081)
|
|
—
|
(Gains) losses on
settled marketing derivatives
|
|
(5,411)
|
|
|
—
|
|
72,687
|
|
—
|
Impairment of oil and
gas properties
|
|
143,369
|
|
|
46,732
|
|
553,907
|
|
1,300,444
|
Impairment of midstream
assets
|
|
—
|
|
|
—
|
|
—
|
|
7,800
|
Impairment of equity
investments
|
|
—
|
|
|
467,590
|
|
—
|
|
467,590
|
Equity-based
compensation
|
|
9,518
|
|
|
4,232
|
|
49,341
|
|
21,082
|
Income from water
earnout
|
|
—
|
|
|
(125,000)
|
|
—
|
|
(125,000)
|
Gain on deconsolidation
of Antero Midstream LP
|
|
—
|
|
|
—
|
|
—
|
|
(1,406,042)
|
Loss on change of fair
value of contingent acquisition consideration
|
|
104,860
|
|
|
—
|
|
93,019
|
|
—
|
Gain on early
extinguishment of debt
|
|
—
|
|
|
(36,419)
|
|
—
|
|
(36,419)
|
Loss on sale of
assets
|
|
—
|
|
|
—
|
|
—
|
|
951
|
Loss on sale of
investment
|
|
|
|
|
108,745
|
|
|
|
108,745
|
Equity in loss of
unconsolidated - AMC
|
|
|
|
|
53,024
|
|
|
|
155,481
|
Contract termination
and rig stacking
|
|
—
|
|
|
—
|
|
—
|
|
14,026
|
Simplification
transaction fees
|
|
—
|
|
|
—
|
|
—
|
|
15,482
|
Tax effect of
reconciling items (1)
|
|
(105,508)
|
|
|
(138,097)
|
|
(237,170)
|
|
(90,163)
|
Other tax items
(2)
|
|
(47,550)
|
|
|
24,041
|
|
(2,987)
|
|
17,528
|
Adjusted Net Income
(Loss)
|
$
|
174,566
|
|
$
|
(6,177)
|
$
|
366,422
|
|
(27,506)
|
|
|
|
|
|
|
|
|
|
|
Fully Diluted Shares
Outstanding
|
|
317,889
|
|
|
300,142
|
|
316,036
|
|
306,400
|
Per Share Amounts
|
Three months
ended
|
|
Year
ended
|
|
December 31,
|
|
December 31,
|
|
2018
|
|
2019
|
|
2018
|
|
|
2019
|
Net loss attributable
to Antero Resources Corp
|
$
|
(0.39)
|
|
$
|
(1.61)
|
$
|
(1.26)
|
|
|
(1.13)
|
Commodity derivative
fair value losses (gains)
|
|
0.71
|
|
|
0.03
|
|
0.28
|
|
|
(1.55)
|
Gains (losses) on
settled commodity derivatives
|
|
(0.08)
|
|
|
0.21
|
|
0.77
|
|
|
1.08
|
Marketing derivative
fair value losses (gains)
|
|
—
|
|
|
—
|
|
(0.30)
|
|
|
—
|
(Gains) losses on
settled marketing derivatives
|
|
(0.02)
|
|
|
—
|
|
0.23
|
|
|
—
|
Impairment of oil and
gas properties
|
|
0.46
|
|
|
0.16
|
|
1.74
|
|
|
4.33
|
Impairment of midstream
assets
|
|
—
|
|
|
—
|
|
—
|
|
|
0.03
|
Impairment of equity
investments
|
|
—
|
|
|
1.56
|
|
—
|
|
|
1.56
|
Equity-based
compensation
|
|
0.03
|
|
|
0.01
|
|
0.16
|
|
|
0.07
|
Income from water
earnout
|
|
|
|
|
(0.42)
|
|
|
|
|
(0.42)
|
Gain on deconsolidation
of Antero Midstream
|
|
—
|
|
|
—
|
|
—
|
|
|
(4.68)
|
Loss on change in fair
value of contingent acquisition consideration
|
|
—
|
|
|
—
|
|
0.29
|
|
|
—
|
Gain on early
extinguishment of debt
|
|
0.34
|
|
|
(0.12)
|
|
—
|
|
|
(0.12)
|
Loss on sale of
assets
|
|
—
|
|
|
—
|
|
—
|
|
|
—
|
Loss on sale of
investment
|
|
—
|
|
|
0.36
|
|
|
|
|
0.36
|
Equity in loss of
unconsolidated - AMC
|
|
—
|
|
|
0.18
|
|
—
|
|
|
0.52
|
Contract termination
and rig stacking
|
|
—
|
|
|
—
|
|
—
|
|
|
0.05
|
Simplification
transaction fees
|
|
—
|
|
|
—
|
|
—
|
|
|
0.05
|
Tax effect of
reconciling items (1)
|
|
(0.34)
|
|
|
(0.46)
|
|
(0.75)
|
|
|
(0.30)
|
Other tax items
(2)
|
|
(0.15)
|
|
|
0.08
|
|
(0.01)
|
|
|
0.06
|
Adjusted Net Income
(Loss)
|
$
|
0.56
|
|
$
|
(0.02)
|
$
|
1.15
|
|
|
(0.09)
|
|
|
|
|
|
|
|
|
|
|
|
Fully Diluted Shares
Outstanding
|
|
317,889
|
|
|
300,142
|
|
316,036
|
|
|
306,400
|
|
|
(1)
|
Deferred taxes
were approximately 24% for 2018 and 23% for 2019.
|
(2)
|
Tax impact in 2018
of valuation allowance on Colorado net operating losses, changes in
statutory tax rate and items effecting the deconsolidated financial
statements.
|
Net Debt
Net Debt is calculated as total debt less cash and cash
equivalents. Management uses Net Debt to evaluate the
Company's financial position, including its ability to service its
debt obligations.
The following table reconciles consolidated total debt to Net
Debt as used in this release (in thousands):
|
|
December
31,
|
|
December
31,
|
|
|
2018
|
|
2019
|
|
|
|
|
|
|
|
AR bank credit
facility
|
|
$
|
405,000
|
|
$
|
552,000
|
AM bank credit
facility (1)
|
|
|
990,000
|
|
|
—
|
5.375% AR senior
notes due 2021
|
|
|
1,000,000
|
|
|
952,500
|
5.125% AR senior
notes due 2022
|
|
|
1,100,000
|
|
|
923,041
|
5.625% AR senior
notes due 2023
|
|
|
750,000
|
|
|
750,000
|
5.375% AM senior
notes due 2024 (1)
|
|
|
650,000
|
|
|
—
|
5.000% AR senior
notes due 2025
|
|
|
600,000
|
|
|
600,000
|
Net unamortized
premium
|
|
|
1,241
|
|
|
791
|
Net unamortized debt
issuance costs (1)
|
|
|
(34,553)
|
|
|
(19,464)
|
Consolidated total
debt
|
|
$
|
5,461,688
|
|
|
3,758,868
|
Less: AR cash and cash
equivalents
|
|
|
—
|
|
|
—
|
Less: AM cash and cash
equivalents (1)
|
|
|
—
|
|
|
—
|
Consolidated net
debt
|
|
$
|
5,461,688
|
|
|
3,758,868
|
|
|
|
|
|
|
|
Less: Antero Midstream
debt net of cash and unamortized premium and debt issuance costs
(1)
|
|
$
|
1,632,147
|
|
|
—
|
Net Debt
|
|
$
|
3,829,541
|
|
$
|
3,758,868
|
|
(1)
Effective March 13, 2019, Antero Midstream is no longer
consolidated in Antero's results
|
Adjusted EBITDAX
Adjusted EBITDAX as defined by the Company represents income or
loss, including noncontrolling interests, before interest expense,
interest income, gains or losses from commodity derivatives and
marketing derivatives, but including net cash receipts or payments
on derivative instruments included in derivative gains or losses
other than proceeds from derivative monetizations, income taxes,
impairment, depletion, depreciation, amortization, and accretion,
exploration expense, equity-based compensation, gain or loss on
early extinguishment of debt, gain or loss on sale of assets, gain
or loss on changes in the fair value of contingent acquisition
consideration, contract termination and rig stacking costs,
distributions from unconsolidated affiliates and equity in earnings
or loss of Antero Midstream. Adjusted EBITDAX also includes
distributions received from limited partner interests in Antero
Midstream common units prior to the closing of the simplification
transaction on March 12, 2019.
The GAAP financial measure nearest to Adjusted EBITDAX is net
income or loss including noncontrolling interest that will be
reported in Antero's condensed consolidated financial
statements. While there are limitations associated with the
use of Adjusted EBITDAX described below, management believes that
this measure is useful to an investor in evaluating the Company's
financial performance because it:
- is widely used by investors in the oil and gas industry to
measure a company's operating performance without regard to items
excluded from the calculation of such term, which can vary
substantially from company to company depending upon accounting
methods and book value of assets, capital structure and the method
by which assets were acquired, among other factors;
- helps investors to more meaningfully evaluate and compare the
results of Antero's operations from period to period by removing
the effect of its capital structure from its operating structure;
and
- is used by management for various purposes, including as a
measure of Antero's operating performance, in presentations to the
Company's board of directors, and as a basis for strategic planning
and forecasting. Adjusted EBITDAX is also used by the board of
directors as a performance measure in determining executive
compensation.
There are significant limitations to using Adjusted EBITDAX as a
measure of performance, including the inability to analyze the
effect of certain recurring and non-recurring items that materially
affect the Company's net income, the lack of comparability of
results of operations of different companies and the different
methods of calculating Adjusted EBITDAX reported by different
companies. In addition, Adjusted EBITDAX provides no
information regarding a company's capital structure, borrowings,
interest costs, capital expenditures, and working capital movement
or tax position.
The following table represents a reconciliation of Adjusted
EBITDAX to net income (loss), including noncontrolling interest to
Adjusted EBITDAX for the periods presented. Adjusted EBITDAX
also excludes the results of Antero Midstream in order to provide
comparability with the current structure of Antero Resources as
Antero Resources no longer consolidates Antero Midstream's results,
effective March 13, 2019. These
Adjustments are disclosed in the table below as Antero Midstream
related adjustments.
|
|
Three months ended
December 31,
|
(in
thousands)
|
|
2018
|
|
2019
|
Reconciliation of
net loss to Adjusted EBITDAX:
|
|
|
|
|
|
|
Net loss and
comprehensive loss attributable to Antero Resources
Corporation
|
|
|
$
(121,546)
|
|
$
|
(482,196)
|
Net income and
comprehensive income attributable to noncontrolling
interests
|
|
|
140,282
|
|
|
—
|
Commodity derivative
fair value gains (1)
|
|
|
222,387
|
|
|
7,875
|
Gains (losses) on
settled commodity derivatives (1)
|
|
|
(25,257)
|
|
|
63,296
|
Gains on settled
marketing derivatives (1)
|
|
|
(5,411)
|
|
|
—
|
Interest expense,
net
|
|
|
78,440
|
|
|
54,243
|
(Gain) loss on early
extinguishment of debt
|
|
|
—
|
|
|
(36,419)
|
Provision for income
tax expense (benefit)
|
|
|
(131,357)
|
|
|
(107,442)
|
Depletion,
depreciation, amortization, and accretion
|
|
|
263,703
|
|
|
191,802
|
Impairment of oil and
gas properties
|
|
|
143,369
|
|
|
46,732
|
Impairment of equity
investments
|
|
|
—
|
|
|
467,590
|
Exploration
expense
|
|
|
936
|
|
|
236
|
Equity-based
compensation expense
|
|
|
13,984
|
|
|
4,232
|
Equity in (earnings)
loss of unconsolidated affiliate
|
|
|
(12,448)
|
|
|
53,023
|
Distributions from
unconsolidated affiliates
|
|
|
16,755
|
|
|
48,715
|
Loss on sale of equity
investment shares
|
|
|
—
|
|
|
108,745
|
Water
earnout
|
|
|
—
|
|
|
(125,000)
|
|
|
|
583,837
|
|
|
295,432
|
Antero Midstream
Related Adjustments (2)
|
|
|
|
|
|
|
Net income and
comprehensive income attributable to noncontrolling
interests
|
|
|
(140,282)
|
|
|
—
|
Antero Midstream
interest expense, net (2)
|
|
|
(18,982)
|
|
|
—
|
Antero Midstream
depreciation, accretion of ARO and accretion of contingent
consideration (2)
|
|
|
82,134
|
|
|
—
|
Antero Midstream
equity-based compensation expense (2)
|
|
|
(4,467)
|
|
|
—
|
Antero Midstream
equity in earnings of unconsolidated affiliates
(2)
|
|
|
12,448
|
|
|
—
|
Antero Midstream
distributions from unconsolidated affiliates
(2)
|
|
|
(16,755)
|
|
|
—
|
Equity in earnings of
Antero Midstream (2)
|
|
|
(66,753)
|
|
|
—
|
Distributions from
Antero Midstream (2)
|
|
|
43,503
|
|
|
—
|
Adjusted
EBITDAX
|
|
$
|
474,683
|
|
$
|
295,432
|
|
|
|
|
|
|
|
|
(1)
The adjustments for the derivative fair value gains and losses
and gains on settled derivatives have the effect of adjusting net
income (loss) from operations for changes in the fair value of
unsettled derivatives, which are recognized at the end of each
accounting period. As a result, derivative gains included in
the calculation Adjusted EBITDAX only reflect derivatives that
settled during the period. The adjustments do not include
proceeds from derivatives monetization.
|
|
(2)
Amounts reflected are net of any elimination adjustments for
intercompany activity and include activity related to Antero
Midstream through March 12, 2019 (date of deconsolidation).
Effective March 13, 2019, Antero accounts for its unconsolidated
investment in Antero Midstream using the equity method of
accounting. See Note 5 to the condensed consolidated
financial statements in Antero's Annual Report on Form 10-K for
the year ended December 31, 2019 for further discussion
on equity method investments.
|
The following table reconciles Antero's net income to Adjusted
EBITDAX for the twelve months ended December 31, 2019, as used
in this release (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Twelve months
ended
|
(in
thousands)
|
|
December 31,
2019
|
Net loss and
comprehensive loss attributable to Antero Resources
Corporation
|
|
$
|
|
|
(340,129)
|
Net income and
comprehensive income attributable to noncontrolling
interests
|
|
|
|
|
46,993
|
Commodity derivative
fair value gains (1)
|
|
|
|
|
(463,972)
|
Losses on settled
commodity derivatives (1)
|
|
|
|
|
325,090
|
Loss on sale of
assets
|
|
|
|
|
951
|
Gain on deconsolidation
of Antero Midstream
|
|
|
|
|
(1,406,042)
|
Interest expense,
net
|
|
|
|
|
228,111
|
Gain on early
extinguishment of debt
|
|
|
|
|
(36,419)
|
Provision for income
tax benefit
|
|
|
|
|
(74,110)
|
Depletion,
depreciation, amortization, and accretion
|
|
|
|
|
918,629
|
Impairment of oil and
gas properties
|
|
|
|
|
1,300,444
|
Impairment of midstream
assets
|
|
|
|
|
14,782
|
Impairment of equity
investments
|
|
|
|
|
467,590
|
Exploration
expense
|
|
|
|
|
884
|
Equity-based
compensation expense
|
|
|
|
|
23,559
|
Equity in loss of
unconsolidated affiliate - AMC
|
|
|
|
|
143,216
|
Distributions from
unconsolidated affiliates
|
|
|
|
|
157,956
|
Contract termination
and rig stacking
|
|
|
|
|
14,026
|
Loss on sale of equity
investment shares
|
|
|
|
|
108,745
|
Water
earnout
|
|
|
|
|
(125,000)
|
Simplification
transaction fees
|
|
|
|
|
15,482
|
|
|
|
|
|
|
Antero Midstream
Related Adjustments (2)
|
|
|
|
|
|
Net income and
comprehensive income attributable to noncontrolling
interests
|
|
|
|
|
(46,993)
|
Antero Midstream
interest expense, net (2)
|
|
|
|
|
(16,815)
|
Antero Midstream loss
on extinguishment of debt
|
|
|
|
|
(21,770)
|
Antero Midstream
depreciation, accretion of ARO and accretion of contingent
consideration (2)
|
|
|
|
|
(6,982)
|
Antero Midstream
impairment
|
|
|
|
|
(2,477)
|
Antero Midstream
equity-based compensation expense (2)
|
|
|
|
|
12,264
|
Antero Midstream gain
on sale (2)
|
|
|
|
|
(61,319)
|
Antero Midstream equity
in earnings of unconsolidated affiliates (2)
|
|
|
|
|
(15,021)
|
Antero Midstream
distributions from unconsolidated affiliates
(2)
|
|
|
|
|
95,183
|
Equity in earnings of
Antero Midstream (2)
|
|
|
|
|
—
|
Distributions from
Antero Midstream (2)
|
|
|
|
|
—
|
Antero Midstream
simplification transaction fees
|
|
|
|
|
(9,185)
|
Adjusted
EBITDAX
|
|
$
|
|
|
1,247,671
|
|
(1)
The adjustments for the derivative fair value gains and losses
and gains on settled derivatives have the effect of adjusting net
income (loss) from operations for changes in the fair value of
unsettled derivatives, which are recognized at the end of each
accounting period. As a result, derivative gains included in
the calculation Adjusted EBITDAX only reflect derivatives that
settled during the period. The adjustments do not include
proceeds from derivatives monetization.
|
|
(2)
Amounts reflected are net of any elimination adjustments for
intercompany activity and include activity related to Antero
Midstream through March 12, 2019 (date of deconsolidation).
Effective March 13, 2019, Antero accounts for its unconsolidated
investment in Antero Midstream using the equity method of
accounting. See Note 5 to the condensed consolidated
financial statements in Antero's Annual Report on Form 10-K for
the year ended December 31, 2019 for further discussion
on equity method investments.
|
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
December 31,
|
|
|
2018
|
|
2019
|
Drilling and
completion costs (as reported; cash basis)
|
|
$
|
362,913
|
|
$
|
296,187
|
Drilling and
completion costs paid to Antero Midstream (cash basis)
(1)
|
|
|
52,385
|
|
|
—
|
Adjusted drilling and
completion costs (cash basis)
|
|
|
415,298
|
|
|
296,187
|
Change in accrued
capital costs
|
|
|
(36,633)
|
|
|
3,441
|
Adjusted drilling and
completion costs (accrual basis)
|
|
$
|
378,665
|
|
$
|
299,628
|
|
(1) Represents drilling and
completion costs paid to Antero Midstream that were consolidated in
Antero Resources' financial results in 2018.
|
F&D Cost & Pre-Tax PV-10 Value
The pre-tax PV-10 value is a non-GAAP financial
measure. Antero believes that the presentation of pre-tax
PV-10 is useful to its investors because it presents the
discounted future net cash flows attributable to reserves prior to
taking into account corporate future income taxes and the Company's
current tax structure. The Company further believes investors
and creditors use pre-tax PV-10 values as a basis for comparison of
the relative size and value of its reserves as compared with other
companies.
The GAAP financial measure most directly comparable to pre-tax
PV-10 is the standardized measure of discounted future net
cash flows ("Standardized Measure"). To reconcile to
Standardized Measure to pre-tax PV-10, the Company reduces
Standardized Measure by the discounted future income taxes
associated with the Company's proved reserves. The following sets
forth the estimated future net cash flows from our proved reserves
(without giving effect to our commodity derivatives), the present
value of those net cash flows before income tax (PV-10) and the
present value of those net cash flows after income tax
(Standardized measure) at December 31,
2019.
(In millions,
except per Mcf data)
|
|
|
At December 31,
2019
|
|
|
|
Future net cash
flows
|
$
|
14,932
|
Present value of
future net cash flows:
|
|
|
Before income tax
(PV-10)
|
$
|
6,067
|
Income
taxes
|
$
|
(598)
|
After income tax
(Standardized measure)
|
$
|
5,469
|
Notwithstanding their use for comparative purposes, the
Company's non-GAAP financial measures may not be comparable to
similarly titled measures employed by other companies.
Antero Resources is an independent natural gas and oil
company engaged in the acquisition, development and production of
unconventional liquids-rich natural gas properties located in the
Appalachian Basin in West Virginia
and Ohio. The Company's website is
located at www.anteroresources.com.
This release includes "forward-looking statements." Such
forward-looking statements are subject to a number of risks and
uncertainties, many of which are not under Antero Resources'
control. All statements, except for statements of historical fact,
made in this release regarding activities, events or developments
Antero Resources expects, believes or anticipates will or may occur
in the future, such as those regarding expected results, future
commodity prices, future production targets, realizing potential
future fee rebates or reductions, including those related to
certain levels of production, future earnings, leverage targets and
debt repayment, future capital spending plans, asset monetization
opportunities and pricing, improved and/or increasing capital
efficiency, estimated realized natural gas, NGL and oil prices,
expected drilling and development plans, projected well costs and
cost savings initiatives, future financial position, the amount and
timing of any litigation settlements, and future marketing
opportunities are forward-looking statements within the meaning of
Section 27A of the Securities Act of 1933 and Section 21E of the
Securities Exchange Act of 1934. All forward-looking statements
speak only as of the date of this release. Although Antero
Resources believes that the plans, intentions and expectations
reflected in or suggested by the forward-looking statements are
reasonable, there is no assurance that these plans, intentions or
expectations will be achieved. Therefore, actual outcomes and
results could materially differ from what is expressed, implied or
forecast in such statements. Except as required by law, Antero
Resources expressly disclaims any obligation to and does not intend
to publicly update or revise any forward-looking
statements.
Antero Resources cautions you that these forward-looking
statements are subject to all of the risks and uncertainties,
incident to the exploration for and development, production,
gathering and sale of natural gas, NGLs and oil most of which are
difficult to predict and many of which are beyond the Antero
Resources' control. These risks include, but are not limited to,
commodity price volatility, inflation, lack of availability of
drilling and production equipment and services, environmental
risks, drilling and other operating risks, regulatory changes, the
uncertainty inherent in estimating natural gas and oil reserves and
in projecting future rates of production, cash flow and access to
capital, the timing of development expenditures, and the other
risks described under the heading "Item 1A. Risk Factors" in Antero
Resources' Annual Report on Form 10-K for the year ended
December 31, 2019.
ANTERO RESOURCES
CORPORATION
|
Consolidated Balance
Sheets
|
December 31,
2018 and 2019
|
(In thousands, except
per share amounts)
|
|
|
|
2018
|
|
2019
|
Assets
|
|
|
|
|
|
Current
assets:
|
|
|
|
|
|
|
Accounts
receivable
|
|
$
|
51,073
|
|
|
46,419
|
Accounts receivable,
related parties
|
|
|
—
|
|
|
125,000
|
Accrued
revenue
|
|
|
474,827
|
|
|
317,886
|
Derivative
instruments
|
|
|
245,263
|
|
|
422,849
|
Other current
assets
|
|
|
35,450
|
|
|
10,731
|
Total current
assets
|
|
|
806,613
|
|
|
922,885
|
Property and
equipment:
|
|
|
|
|
|
|
Oil and gas
properties, at cost (successful efforts method):
|
|
|
|
|
|
|
Unproved
properties
|
|
|
1,767,600
|
|
|
1,368,854
|
Proved
properties
|
|
|
12,705,672
|
|
|
11,859,817
|
Water handling and
treatment systems
|
|
|
1,013,818
|
|
|
—
|
Gathering systems and
facilities
|
|
|
2,470,708
|
|
|
5,802
|
Other property and
equipment
|
|
|
65,842
|
|
|
71,895
|
|
|
|
18,023,640
|
|
|
13,306,368
|
Less accumulated
depletion, depreciation, and amortization
|
|
|
(4,153,725)
|
|
|
(3,327,629)
|
Property and
equipment, net
|
|
|
13,869,915
|
|
|
9,978,739
|
Operating leases
right-of-use assets
|
|
|
—
|
|
|
2,886,500
|
Derivative
instruments
|
|
|
362,169
|
|
|
333,174
|
Investments in
unconsolidated affiliates
|
|
|
433,642
|
|
|
1,055,177
|
Other
assets
|
|
|
47,125
|
|
|
21,094
|
Total
assets
|
|
$
|
15,519,464
|
|
|
15,197,569
|
|
|
|
|
|
|
|
Liabilities and
Equity
|
|
|
|
|
|
Current
liabilities:
|
|
|
|
|
|
|
Accounts
payable
|
|
$
|
66,289
|
|
|
14,498
|
Accounts payable,
related parties
|
|
|
—
|
|
|
97,883
|
Accrued
liabilities
|
|
|
465,070
|
|
|
400,850
|
Revenue distributions
payable
|
|
|
310,827
|
|
|
207,988
|
Derivative
instruments
|
|
|
532
|
|
|
6,721
|
Short-term lease
liabilities
|
|
|
2,459
|
|
|
305,320
|
Other current
liabilities
|
|
|
8,363
|
|
|
6,879
|
Total current
liabilities
|
|
|
853,540
|
|
|
1,040,139
|
Long-term
liabilities:
|
|
|
|
|
|
|
Long-term
debt
|
|
|
5,461,688
|
|
|
3,758,868
|
Deferred income tax
liability
|
|
|
650,788
|
|
|
781,987
|
Derivative
instruments
|
|
|
—
|
|
|
3,519
|
Long-term lease
liabilities
|
|
|
2,873
|
|
|
2,583,678
|
Other
liabilities
|
|
|
63,098
|
|
|
58,635
|
Total
liabilities
|
|
|
7,031,987
|
|
|
8,226,826
|
Commitments and
contingencies (Notes 14 and 15)
|
|
|
|
|
|
|
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; 308,594 shares and
295,941 shares issued and outstanding at December 31, 2018 and
2019, respectively
|
|
|
3,086
|
|
|
2,959
|
Additional paid-in
capital
|
|
|
6,485,174
|
|
|
6,130,365
|
Accumulated
earnings
|
|
|
1,177,548
|
|
|
837,419
|
Total stockholders'
equity
|
|
|
7,665,808
|
|
|
6,970,743
|
Noncontrolling
interests in consolidated subsidiary
|
|
|
821,669
|
|
|
—
|
Total
equity
|
|
|
8,487,477
|
|
|
6,970,743
|
Total liabilities and
equity
|
|
$
|
15,519,464
|
|
|
15,197,569
|
ANTERO RESOURCES
CORPORATION
|
Condensed
Consolidated Statements of Operations and Comprehensive Income
(Loss)
|
Three Months and
Years Ended December 31, 2018 and 2019
|
(In thousands, except
per share amounts)
|
|
|
|
Three Months Ended
December 31,
|
|
Year Ended
December 31,
|
|
|
2018
|
|
2019
|
|
2018
|
|
2019
|
Revenue and
other:
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas
sales
|
|
$
|
789,614
|
|
|
512,076
|
|
$
|
2,287,939
|
|
|
2,247,162
|
Natural gas liquids
sales
|
|
|
349,353
|
|
|
316,556
|
|
|
1,177,777
|
|
|
1,219,162
|
Oil sales
|
|
|
58,310
|
|
|
39,874
|
|
|
187,178
|
|
|
177,549
|
Commodity derivative
fair value gains (losses)
|
|
|
(222,386)
|
|
|
(7,875)
|
|
|
(87,594)
|
|
|
463,972
|
Gathering,
compression, water handling and treatment
|
|
|
6,047
|
|
|
—
|
|
|
21,344
|
|
|
4,478
|
Marketing
|
|
|
64,712
|
|
|
91,296
|
|
|
458,901
|
|
|
292,207
|
Marketing derivative
fair value gains (losses)
|
|
|
(1)
|
|
|
—
|
|
|
94,081
|
|
|
—
|
Other
income
|
|
|
—
|
|
|
811
|
|
|
—
|
|
|
4,160
|
Total revenue and
other
|
|
|
1,045,649
|
|
|
952,738
|
|
|
4,139,626
|
|
|
4,408,690
|
Operating
expenses:
|
|
|
|
|
|
—
|
|
|
|
|
|
|
Lease
operating
|
|
|
42,998
|
|
|
27,203
|
|
|
136,153
|
|
|
145,720
|
Gathering,
compression, processing, and transportation
|
|
|
413,130
|
|
|
551,424
|
|
|
1,339,358
|
|
|
2,146,647
|
Production and ad
valorem taxes
|
|
|
44,242
|
|
|
29,633
|
|
|
126,474
|
|
|
125,142
|
Marketing
|
|
|
125,132
|
|
|
140,975
|
|
|
686,055
|
|
|
549,814
|
Exploration
|
|
|
936
|
|
|
236
|
|
|
4,958
|
|
|
884
|
Impairment of oil and
gas properties
|
|
|
143,370
|
|
|
46,732
|
|
|
549,437
|
|
|
1,300,444
|
Impairment of
midstream assets
|
|
|
—
|
|
|
14,782
|
|
|
9,658
|
|
|
14,782
|
Depletion,
depreciation, and amortization
|
|
|
262,985
|
|
|
190,861
|
|
|
972,465
|
|
|
914,867
|
Loss on sale of
assets
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
951
|
Accretion of asset
retirement obligations
|
|
|
719
|
|
|
941
|
|
|
2,819
|
|
|
3,762
|
General and
administrative (including equity-based compensation expense
)
|
|
|
58,767
|
|
|
32,189
|
|
|
240,344
|
|
|
178,696
|
Contract termination
and rig stacking
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
14,026
|
Total operating
expenses
|
|
|
1,092,279
|
|
|
1,034,976
|
|
|
4,067,721
|
|
|
5,395,735
|
Operating income
(loss)
|
|
|
(46,630)
|
|
|
(82,238)
|
|
|
71,905
|
|
|
(987,045)
|
Other income
(expenses):
|
|
|
|
|
|
—
|
|
|
|
|
|
|
Water
earnout
|
|
|
—
|
|
|
125,000
|
|
|
—
|
|
|
125,000
|
Equity in earnings
(loss) of unconsolidated affiliates
|
|
|
12,449
|
|
|
(53,023)
|
|
|
40,280
|
|
|
(143,216)
|
Loss on the sale of
equity investment shares
|
|
|
—
|
|
|
(108,745)
|
|
|
—
|
|
|
(108,745)
|
Impairment of equity
investments
|
|
|
—
|
|
|
(467,590)
|
|
|
—
|
|
|
(467,590)
|
Gain on
deconsolidation of Antero Midstream Partners LP
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1,406,042
|
Interest expense,
net
|
|
|
(78,440)
|
|
|
(54,243)
|
|
|
(286,743)
|
|
|
(228,111)
|
Gain (loss) on early
extinguishment of debt
|
|
|
—
|
|
|
36,419
|
|
|
—
|
|
|
36,419
|
Total other income
(expenses)
|
|
|
(65,991)
|
|
|
(522,182)
|
|
|
(246,463)
|
|
|
619,799
|
Loss before income
taxes
|
|
|
(112,621)
|
|
|
(589,638)
|
|
|
(174,558)
|
|
|
(367,246)
|
Provision for income
tax benefit
|
|
|
131,357
|
|
|
107,442
|
|
|
128,857
|
|
|
74,110
|
Net income (loss) and
comprehensive income (loss) including noncontrolling
interests
|
|
|
18,736
|
|
|
(482,196)
|
|
|
(45,701)
|
|
|
(293,136)
|
Net income and
comprehensive income attributable to noncontrolling
interests
|
|
|
140,282
|
|
|
—
|
|
|
351,816
|
|
|
46,993
|
Net income (loss) and
comprehensive income (loss) attributable to Antero Resources
Corporation
|
|
$
|
(121,546)
|
|
|
(482,196)
|
|
$
|
(397,517)
|
|
|
(340,129)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) per
common share—basic
|
|
$
|
(0.39)
|
|
|
(1.61)
|
|
$
|
(1.26)
|
|
|
(1.11)
|
Income (loss) per
common share—assuming dilution
|
|
$
|
(0.39)
|
|
|
(1.61)
|
|
$
|
(1.26)
|
|
|
(1.11)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average
number of shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
313,618
|
|
|
300,142
|
|
|
316,036
|
|
|
306,400
|
Diluted
|
|
|
313,618
|
|
|
300,142
|
|
|
316,036
|
|
|
306,400
|
ANTERO RESOURCES
CORPORATION
|
Condensed
Consolidated Statements of Cash Flows
|
Years Ended
December 31, 2017, 2018 and 2019
|
(Unaudited)
|
(In
thousands)
|
|
|
|
Year Ended
December 31,
|
|
|
2017
|
|
2018
|
|
2019
|
Cash flows provided
by (used in) operating activities:
|
|
|
|
|
|
|
|
|
|
Net income (loss) and
comprehensive income (loss) including noncontrolling
interests
|
|
$
|
785,137
|
|
|
(45,701)
|
|
|
(293,136)
|
Adjustments to
reconcile net income (loss) to net cash provided by operating
activities:
|
|
|
|
|
|
|
|
|
|
Depletion,
depreciation, amortization, and accretion
|
|
|
827,220
|
|
|
975,284
|
|
|
918,629
|
Impairments
|
|
|
183,029
|
|
|
559,095
|
|
|
1,782,816
|
Commodity derivative
fair value (gains) losses
|
|
|
(658,283)
|
|
|
87,594
|
|
|
(463,972)
|
Gains on settled
commodity derivatives
|
|
|
213,940
|
|
|
243,112
|
|
|
325,090
|
Premium paid on
derivative contracts
|
|
|
—
|
|
|
(13,318)
|
|
|
—
|
Proceeds from
derivative monetizations
|
|
|
749,906
|
|
|
370,365
|
|
|
—
|
Marketing derivative
fair value gains
|
|
|
21,394
|
|
|
(94,081)
|
|
|
—
|
Gains on settled
marketing derivatives
|
|
|
—
|
|
|
72,687
|
|
|
—
|
Deferred income tax
benefit
|
|
|
(295,126)
|
|
|
(128,857)
|
|
|
(79,158)
|
Loss on sale of
assets
|
|
|
—
|
|
|
—
|
|
|
951
|
Equity-based
compensation expense
|
|
|
103,445
|
|
|
70,414
|
|
|
23,559
|
Loss (gain) on early
extinguishment of debt
|
|
|
1,500
|
|
|
—
|
|
|
(36,419)
|
Loss on sale of Antero
Midstream Corporation shares
|
|
|
—
|
|
|
—
|
|
|
108,745
|
Equity in earnings
(loss) of unconsolidated affiliates
|
|
|
(20,194)
|
|
|
(40,280)
|
|
|
143,216
|
Water
earnout
|
|
|
—
|
|
|
—
|
|
|
(125,000)
|
Distributions/dividends of earnings from
unconsolidated affiliates
|
|
|
20,195
|
|
|
46,415
|
|
|
157,956
|
Gain on
deconsolidation of Antero Midstream Partners LP
|
|
|
—
|
|
|
—
|
|
|
(1,406,042)
|
Other
|
|
|
(1,907)
|
|
|
4,681
|
|
|
10,681
|
Changes in current
assets and liabilities:
|
|
|
|
|
|
|
|
|
|
Accounts
receivable
|
|
|
(5,214)
|
|
|
(15,156)
|
|
|
31,631
|
Accrued
revenue
|
|
|
(38,162)
|
|
|
(174,706)
|
|
|
156,941
|
Other current
assets
|
|
|
(2,755)
|
|
|
(5,817)
|
|
|
(1,025)
|
Accounts payable
including related parties
|
|
|
9,462
|
|
|
9,307
|
|
|
(27,996)
|
Accrued
liabilities
|
|
|
64,862
|
|
|
63,562
|
|
|
(25,762)
|
Revenue distributions
payable
|
|
|
45,628
|
|
|
101,210
|
|
|
(102,839)
|
Other current
liabilities
|
|
|
2,214
|
|
|
(3,823)
|
|
|
4,592
|
Net cash provided by
operating activities
|
|
|
2,006,291
|
|
|
2,081,987
|
|
|
1,103,458
|
Cash flows provided
by (used in) investing activities:
|
|
|
|
|
|
|
|
|
|
Additions to proved
properties
|
|
|
(175,650)
|
|
|
—
|
|
|
—
|
Additions to unproved
properties
|
|
|
(204,272)
|
|
|
(172,387)
|
|
|
(88,682)
|
Drilling and
completion costs
|
|
|
(1,281,985)
|
|
|
(1,488,573)
|
|
|
(1,254,118)
|
Additions to water
handling and treatment systems
|
|
|
(194,502)
|
|
|
(97,699)
|
|
|
(24,416)
|
Additions to gathering
systems and facilities
|
|
|
(346,217)
|
|
|
(444,413)
|
|
|
(48,239)
|
Additions to other
property and equipment
|
|
|
(14,127)
|
|
|
(7,514)
|
|
|
(6,700)
|
Investments in
unconsolidated affiliates
|
|
|
(235,004)
|
|
|
(136,475)
|
|
|
(25,020)
|
Proceeds from sale of
common stock of Antero Midstream Corporation
|
|
|
—
|
|
|
—
|
|
|
100,000
|
Proceeds from the
Antero Midstream Partners LP Transactions
|
|
|
—
|
|
|
—
|
|
|
296,611
|
Change in other
assets
|
|
|
(12,029)
|
|
|
(3,663)
|
|
|
7,091
|
Proceeds from asset
sales
|
|
|
2,156
|
|
|
—
|
|
|
1,983
|
Net cash used in
investing activities
|
|
|
(2,461,630)
|
|
|
(2,350,724)
|
|
|
(1,041,490)
|
Cash flows provided
by (used in) financing activities:
|
|
|
|
|
|
|
|
|
|
Issuance of common
units by Antero Midstream Partners LP
|
|
|
248,956
|
|
|
—
|
|
|
—
|
Proceeds from sale of
common units of Antero Midstream Partners LP held by Antero
Resources Corporation
|
|
|
311,100
|
|
|
—
|
|
|
—
|
Repurchases of common
stock
|
|
|
—
|
|
|
(129,084)
|
|
|
(38,772)
|
Issuance of senior
notes by Antero Midstream Partners LP
|
|
|
—
|
|
|
—
|
|
|
650,000
|
Repayment of senior
notes
|
|
|
—
|
|
|
—
|
|
|
(191,092)
|
Borrowings on bank
credit facilities, net
|
|
|
90,000
|
|
|
660,379
|
|
|
232,000
|
Payments of deferred
financing costs
|
|
|
(16,377)
|
|
|
(2,169)
|
|
|
(4,547)
|
Distributions to
noncontrolling interests in Antero Midstream Partners LP
|
|
|
(152,352)
|
|
|
(267,271)
|
|
|
(85,076)
|
Employee tax
withholding for settlement of equity compensation awards
|
|
|
(24,174)
|
|
|
(17,020)
|
|
|
(2,389)
|
Other
|
|
|
(4,983)
|
|
|
(4,539)
|
|
|
(2,560)
|
Net cash provided by
financing activities
|
|
|
452,170
|
|
|
240,296
|
|
|
557,564
|
Antero Midstream
Partners LP cash at deconsolidation
|
|
|
—
|
|
|
—
|
|
|
(619,532)
|
Net decrease in cash
and cash equivalents
|
|
|
(3,169)
|
|
|
(28,441)
|
|
|
—
|
Cash and cash
equivalents, beginning of period
|
|
|
31,610
|
|
|
28,441
|
|
|
—
|
Cash and cash
equivalents, end of period
|
|
$
|
28,441
|
|
|
—
|
|
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended
December 31,
|
|
|
2017
|
|
2018
|
|
2019
|
Supplemental
disclosure of cash flow information:
|
|
|
|
|
|
|
|
|
|
Cash paid during the
period for interest
|
|
$
|
263,919
|
|
|
275,769
|
|
|
224,331
|
Decrease in accounts
payable and accrued liabilities for additions to property and
equipment
|
|
$
|
(547)
|
|
|
(47,717)
|
|
|
(15,897)
|
The following table
set forth selected operating data for the three months ended
December 31, 2018 and 2019:
|
|
|
|
|
|
|
|
|
|
|
Three months ended
December 31,
|
|
Amount of
Increase
|
|
Percent
|
|
(in thousands)
|
|
2018
|
|
2019
|
|
(Decrease)
|
|
Change
|
|
Revenue:
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas
sales
|
|
$
|
789,614
|
|
$
|
512,076
|
|
$
|
(277,538)
|
|
(35)
|
%
|
NGLs sales
|
|
|
349,353
|
|
|
316,556
|
|
|
(32,797)
|
|
(9)
|
%
|
Oil sales
|
|
|
58,310
|
|
|
39,874
|
|
|
(18,436)
|
|
(32)
|
%
|
Commodity derivative
fair value gains (losses)
|
|
|
(22,386)
|
|
|
(7,875)
|
|
|
14,511
|
|
(65)
|
%
|
Gathering, compression,
water handling and treatment
|
|
|
6,047
|
|
|
—
|
|
|
(6,047)
|
|
(100)
|
%
|
Marketing
|
|
|
64,712
|
|
|
91,296
|
|
|
26,584
|
|
41
|
%
|
Other income
|
|
|
(1)
|
|
|
811
|
|
|
812
|
|
*
|
|
Total operating
revenues and other
|
|
|
1,045,649
|
|
|
952,738
|
|
|
(92,911)
|
|
(9)
|
%
|
Operating
expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease
operating
|
|
|
42,998
|
|
|
27,203
|
|
|
(15,795)
|
|
(37)
|
%
|
Gathering, compression,
processing, and transportation
|
|
|
413,130
|
|
|
551,424
|
|
|
138,294
|
|
33
|
%
|
Production and ad
valorem taxes
|
|
|
44,242
|
|
|
29,633
|
|
|
(14,609)
|
|
(33)
|
%
|
Marketing
|
|
|
125,132
|
|
|
140,975
|
|
|
15,843
|
|
13
|
%
|
Exploration
|
|
|
936
|
|
|
236
|
|
|
(700)
|
|
(75)
|
%
|
Impairment of oil and
gas properties
|
|
|
143,370
|
|
|
46,732
|
|
|
(96,638)
|
|
(67)
|
%
|
Impairment of midstream
assets
|
|
|
—
|
|
|
14,782
|
|
|
14,782
|
|
*
|
|
Depletion,
depreciation, and amortization
|
|
|
262,985
|
|
|
190,861
|
|
|
(72,124)
|
|
(27)
|
%
|
Accretion of asset
retirement obligations
|
|
|
719
|
|
|
941
|
|
|
222
|
|
31
|
%
|
General and
administrative (excluding equity-based compensation)
|
|
|
44,782
|
|
|
27,957
|
|
|
(16,825)
|
|
(38)
|
%
|
Equity-based
compensation
|
|
|
13,985
|
|
|
4,232
|
|
|
(9,753)
|
|
(70)
|
%
|
Total operating
expenses
|
|
|
1,092,279
|
|
|
1,034,976
|
|
|
(57,303)
|
|
(5)
|
%
|
Operating income
(loss)
|
|
|
(46,630)
|
|
|
(82,238)
|
|
|
(35,608)
|
|
76
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other earnings
(expenses):
|
|
|
|
|
|
|
|
|
|
|
|
|
Water
earnout
|
|
|
—
|
|
|
125,000
|
|
|
(125,000)
|
|
*
|
|
Equity in earnings of
unconsolidated affiliates
|
|
|
12,449
|
|
|
(53,023)
|
|
|
(65,472)
|
|
(526)
|
%
|
Loss on the sale of
equity investment shares
|
|
|
—
|
|
|
(108,745)
|
|
|
(108,745)
|
|
*
|
|
Impairment of equity
investments
|
|
|
—
|
|
|
(467,590)
|
|
|
467,590
|
|
*
|
|
Interest
expense
|
|
|
(78,440)
|
|
|
(54,243)
|
|
|
24,197
|
|
(31)
|
%
|
Gain on early
extinguishment of debt
|
|
|
—
|
|
|
36,419
|
|
|
36,419
|
|
*
|
|
Total other
expenses
|
|
|
(65,991)
|
|
|
(522,182)
|
|
|
(456,191)
|
|
691
|
%
|
Loss before income
taxes
|
|
|
(112,621)
|
|
|
(604,420)
|
|
|
(491,799)
|
|
437
|
%
|
Income tax
benefit
|
|
|
131,357
|
|
|
107,442
|
|
|
(23,915)
|
|
*
|
|
Net loss and
comprehensive loss including noncontrolling interest
|
|
|
18,736
|
|
|
(496,978)
|
|
|
(515,714)
|
|
*
|
|
Net income and
comprehensive income attributable to noncontrolling
interest
|
|
|
140,282
|
|
|
—
|
|
|
(140,282)
|
|
(100)
|
%
|
Net loss and
comprehensive loss attributable to Antero Resources
Corporation
|
|
$
|
(121,546)
|
|
$
|
(496,978)
|
|
|
(375,432)
|
|
309
|
%
|
|
|
|
|
|
|
|
|
|
—
|
|
|
|
Adjusted
EBITDAX
|
|
$
|
456,722
|
|
$
|
295,728
|
|
$
|
(160,994)
|
|
(35)
|
%
|
The following table
set forth selected operating data for the three months ended
December 31, 2018 and 2019:
|
|
|
|
Three months ended
December 31,
|
|
Amount of
Increase
|
|
Percent
|
|
|
|
2018
|
|
2019
|
|
(Decrease)
|
|
Change
|
|
Production
data:
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas
(Bcf)
|
|
|
206
|
|
|
205
|
|
|
(1)
|
|
(0)
|
%
|
C2 Ethane
(MBbl)
|
|
|
4,323
|
|
|
4,325
|
|
|
2
|
|
0
|
%
|
C3+ NGLs
(MBbl)
|
|
|
9,463
|
|
|
9,603
|
|
|
140
|
|
1
|
%
|
Oil (MBbl)
|
|
|
1,125
|
|
|
809
|
|
|
(316)
|
|
(28)
|
%
|
Combined
(Bcfe)
|
|
|
296
|
|
|
293
|
|
|
(3)
|
|
(1)
|
%
|
Daily combined
production (MMcfe/d)
|
|
|
3,213
|
|
|
3,185
|
|
|
(28)
|
|
(1)
|
%
|
Average prices
before effects of derivative settlements
(1):
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas (per Mcf)
(2)
|
|
$
|
3.83
|
|
$
|
2.50
|
|
$
|
(1.33)
|
|
(35)
|
%
|
C2 Ethane (per
Bbl)
|
|
$
|
13.12
|
|
$
|
7.44
|
|
$
|
(5.68)
|
|
(43)
|
%
|
C3+ NGLs (per
Bbl)
|
|
$
|
30.92
|
|
$
|
29.61
|
|
$
|
(1.31)
|
|
(4)
|
%
|
Oil (per
Bbl)
|
|
$
|
51.83
|
|
$
|
49.29
|
|
$
|
(2.54)
|
|
(5)
|
%
|
Weighted Average
Combined (per Mcfe)
|
|
$
|
4.05
|
|
$
|
2.96
|
|
$
|
(1.09)
|
|
(27)
|
%
|
Average realized
prices after effects of derivative settlements
(1):
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas (per
Mcf)
|
|
$
|
3.73
|
|
$
|
2.87
|
|
$
|
(0.86)
|
|
(23)
|
%
|
C2 Ethane (per
Bbl)
|
|
$
|
13.12
|
|
$
|
7.44
|
|
$
|
(5.68)
|
|
(43)
|
%
|
C3+ NGLs (per
Bbl)
|
|
$
|
30.60
|
|
$
|
27.95
|
|
$
|
(2.65)
|
|
(9)
|
%
|
Oil (per
Bbl)
|
|
$
|
50.92
|
|
$
|
53.57
|
|
$
|
2.65
|
|
5
|
%
|
Weighted Average
Combined (per Mcfe)
|
|
$
|
3.97
|
|
$
|
3.18
|
|
$
|
(0.79)
|
|
(20)
|
%
|
Average costs (per
Mcfe):
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease
operating
|
|
$
|
0.15
|
|
$
|
0.09
|
|
$
|
(0.06)
|
|
(40)
|
%
|
Gathering,
compression, processing, and transportation
|
|
$
|
1.88
|
|
$
|
1.88
|
|
$
|
—
|
|
—
|
%
|
Production and ad
valorem taxes
|
|
$
|
0.15
|
|
$
|
0.10
|
|
$
|
(0.05)
|
|
(33)
|
%
|
Marketing expense,
net
|
|
$
|
0.20
|
|
$
|
0.17
|
|
$
|
(0.03)
|
|
(15)
|
%
|
Depletion,
depreciation, amortization, and accretion
|
|
$
|
0.82
|
|
$
|
0.65
|
|
$
|
(0.17)
|
|
(21)
|
%
|
General and
administrative (excluding equity-based compensation)
|
|
$
|
0.11
|
|
$
|
0.10
|
|
$
|
(0.01)
|
|
(9)
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended
December 31,
|
|
Amount of
Increase
|
|
Percent
|
|
(in thousands)
|
|
2018
|
|
2019
|
|
(Decrease)
|
|
Change
|
|
Operating revenues
and other:
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas
sales
|
|
$
|
2,287,939
|
|
$
|
2,247,162
|
|
$
|
(40,777)
|
|
(2)
|
%
|
NGLs sales
|
|
|
1,177,777
|
|
|
1,219,162
|
|
|
41,385
|
|
4
|
%
|
Oil sales
|
|
|
187,178
|
|
|
177,549
|
|
|
(9,629)
|
|
(5)
|
%
|
Commodity derivative
fair value gains (losses)
|
|
|
(87,594)
|
|
|
463,972
|
|
|
551,566
|
|
(630)
|
%
|
Gathering, compression,
water handling and treatment
|
|
|
21,344
|
|
|
4,478
|
|
|
(16,866)
|
|
(79)
|
%
|
Marketing
|
|
|
458,901
|
|
|
292,207
|
|
|
(166,694)
|
|
(36)
|
%
|
Marketing derivative
fair value gains
|
|
|
94,081
|
|
|
—
|
|
|
(94,081)
|
|
(100)
|
%
|
Other income
|
|
|
—
|
|
|
4,160
|
|
|
4,160
|
|
*
|
|
Total operating
revenues and other
|
|
|
4,139,626
|
|
|
4,408,690
|
|
|
269,064
|
|
6
|
%
|
Operating
expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease
operating
|
|
|
136,153
|
|
|
145,720
|
|
|
9,567
|
|
7
|
%
|
Gathering, compression,
processing, and transportation
|
|
|
1,339,358
|
|
|
2,146,647
|
|
|
807,289
|
|
60
|
%
|
Water
earnout
|
|
|
—
|
|
|
(125,000)
|
|
|
(125,000)
|
|
*
|
|
Production and ad
valorem taxes
|
|
|
126,474
|
|
|
125,142
|
|
|
(1,332)
|
|
(1)
|
%
|
Marketing
|
|
|
686,055
|
|
|
549,814
|
|
|
(136,241)
|
|
(20)
|
%
|
Exploration
|
|
|
4,958
|
|
|
884
|
|
|
(4,074)
|
|
(82)
|
%
|
Impairment of oil and
gas properties
|
|
|
549,437
|
|
|
1,300,444
|
|
|
751,007
|
|
137
|
%
|
Impairment of midstream
assets
|
|
|
9,658
|
|
|
14,782
|
|
|
5,124
|
|
53
|
%
|
Depletion,
depreciation, and amortization
|
|
|
972,465
|
|
|
914,867
|
|
|
(57,598)
|
|
(6)
|
%
|
Loss on sale of
assets
|
|
|
—
|
|
|
951
|
|
|
951
|
|
*
|
|
Accretion of asset
retirement obligations
|
|
|
2,819
|
|
|
3,762
|
|
|
943
|
|
33
|
%
|
General and
administrative (excluding equity-based compensation)
|
|
|
169,930
|
|
|
155,137
|
|
|
(14,793)
|
|
(9)
|
%
|
Equity-based
compensation
|
|
|
70,414
|
|
|
23,559
|
|
|
(46,855)
|
|
(67)
|
%
|
Contract termination
and rig stacking
|
|
|
—
|
|
|
14,026
|
|
|
14,026
|
|
*
|
|
Total operating
expenses
|
|
|
4,067,721
|
|
|
5,270,735
|
|
|
1,203,014
|
|
30
|
%
|
Operating income
(loss)
|
|
|
71,905
|
|
|
(862,045)
|
|
|
(933,950)
|
|
(1,299)
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other earnings
(expenses):
|
|
|
|
|
|
|
|
|
|
|
|
|
Water
earnout
|
|
|
—
|
|
|
125,000
|
|
|
125,000
|
|
*
|
|
Equity in earnings of
unconsolidated affiliates
|
|
|
40,280
|
|
|
(143,216)
|
|
|
(183,496)
|
|
(456)
|
|
Loss on the sale of
equity investment shares
|
|
|
—
|
|
|
(108,745)
|
|
|
(108,745)
|
|
*
|
|
Gain on deconsolidation
of Antero Midstream Partners LP
|
|
|
—
|
|
|
1,406,042
|
|
|
1,406,042
|
|
*
|
|
Impairment of equity
investments
|
|
|
—
|
|
|
(467,590)
|
|
|
(467,590)
|
|
*
|
|
Interest
expense
|
|
|
(286,743)
|
|
|
(228,111)
|
|
|
58,632
|
|
(20)
|
|
Gain on early
extinguishment of debt
|
|
|
—
|
|
|
36,419
|
|
|
36,419
|
|
*
|
|
Total other
expenses
|
|
|
(246,463)
|
|
|
494,799
|
|
|
741,262
|
|
(301)
|
%
|
Loss before income
taxes
|
|
|
(174,558)
|
|
|
(367,246)
|
|
|
(192,688)
|
|
110
|
%
|
Income tax
benefit
|
|
|
128,857
|
|
|
74,110
|
|
|
(54,747)
|
|
(42)
|
%
|
Net loss and
comprehensive loss including noncontrolling interest
|
|
|
(45,701)
|
|
|
(293,136)
|
|
|
(247,435)
|
|
541
|
%
|
Net income and
comprehensive income attributable to noncontrolling
interest
|
|
|
351,816
|
|
|
46,993
|
|
|
(304,823)
|
|
(87)
|
%
|
Net loss and
comprehensive loss attributable to Antero Resources
Corporation
|
|
$
|
(397,517)
|
|
$
|
(340,129)
|
|
$
|
57,388
|
|
(14)
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted
EBITDAX
|
|
$
|
1,717,120
|
|
$
|
1,247,967
|
|
$
|
(469,153)
|
|
(27)
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended
December 31,
|
|
Amount of
Increase
|
|
Percent
|
|
|
|
2018
|
|
2019
|
|
(Decrease)
|
|
Change
|
|
Production
data:
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas
(Bcf)
|
|
|
710
|
|
|
822
|
|
|
112
|
|
16
|
%
|
C2 Ethane
(MBbl)
|
|
|
14,221
|
|
|
15,861
|
|
|
1,640
|
|
12
|
%
|
C3+ NGLs
(MBbl)
|
|
|
28,913
|
|
|
39,445
|
|
|
10,532
|
|
36
|
%
|
Oil (MBbl)
|
|
|
3,265
|
|
|
3,632
|
|
|
367
|
|
11
|
%
|
Combined
(Bcfe)
|
|
|
989
|
|
|
1,175
|
|
|
186
|
|
19
|
%
|
Daily combined
production (MMcfe/d)
|
|
|
2,709
|
|
|
3,220
|
|
|
511
|
|
19
|
%
|
Average prices
before effects of derivative settlements
(1):
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas (per Mcf)
(2)
|
|
$
|
3.22
|
|
$
|
2.74
|
|
$
|
(0.48)
|
|
(15)
|
%
|
C2 Ethane (per
Bbl)
|
|
$
|
12.14
|
|
$
|
7.85
|
|
$
|
(4.29)
|
|
(35)
|
%
|
C3+ NGLs (per
Bbl)
|
|
$
|
34.76
|
|
$
|
27.75
|
|
$
|
(7.01)
|
|
(20)
|
%
|
Oil (per
Bbl)
|
|
$
|
57.34
|
|
$
|
48.88
|
|
$
|
(8.46)
|
|
(15)
|
%
|
Weighted Average
Combined (per Mcfe)
|
|
$
|
3.69
|
|
$
|
3.10
|
|
$
|
(0.59)
|
|
(16)
|
%
|
Average realized
prices after effects of derivative settlements
(1):
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas (per
Mcf)
|
|
$
|
3.65
|
|
$
|
3.14
|
|
$
|
(0.51)
|
|
(14)
|
%
|
C2 Ethane (per
Bbl)
|
|
$
|
12.14
|
|
$
|
7.85
|
|
$
|
(4.29)
|
|
(35)
|
%
|
C3+ NGLs (per
Bbl)
|
|
$
|
33.25
|
|
$
|
27.41
|
|
$
|
(5.84)
|
|
(18)
|
%
|
Oil (per
Bbl)
|
|
$
|
52.11
|
|
$
|
50.92
|
|
$
|
(1.19)
|
|
(2)
|
%
|
Weighted Average
Combined (per Mcfe)
|
|
$
|
3.94
|
|
$
|
3.38
|
|
$
|
(0.56)
|
|
(14)
|
%
|
Average costs (per
Mcfe):
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease
operating
|
|
$
|
0.14
|
|
$
|
0.13
|
|
$
|
(0.01)
|
|
(7)
|
%
|
Gathering,
compression, processing, and transportation
|
|
$
|
1.81
|
|
$
|
1.92
|
|
$
|
0.11
|
|
6
|
%
|
Production and ad
valorem taxes
|
|
$
|
0.12
|
|
$
|
0.11
|
|
$
|
(0.01)
|
|
(8)
|
%
|
Marketing expense
(gain), net
|
|
$
|
0.23
|
|
$
|
0.22
|
|
$
|
(0.01)
|
|
(4)
|
%
|
Depletion,
depreciation, amortization, and accretion
|
|
$
|
0.85
|
|
$
|
0.76
|
|
$
|
(0.09)
|
|
(11)
|
%
|
General and
administrative (excluding equity-based compensation)
|
|
$
|
0.13
|
|
$
|
0.12
|
|
$
|
(0.01)
|
|
(8)
|
%
|
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SOURCE Antero Resources Corporation