Antero Reports Mid-Year 2014 Reserves

                    Antero Reports Mid-Year 2014 Reserves

PR Newswire

DENVER, July 15, 2014

DENVER, July 15, 2014 /PRNewswire/ --

  oMid-year 2014 proved reserves increased by 19% to 9.1 Tcfe (13% liquids)
    from year-end 2013
  oProved developed reserves increased by 37% to 2.8 Tcfe (12% liquids)
  oPre-tax PV10 of proved reserves including hedges increased by 28% to $9.0
    billion
  o3P reserves increased by 7% to 37.5 Tcfe (15% liquids)
  oPre-tax PV10 of 3P reserves including hedges increased by 24% to $26.4
    billion
  oUtica Shale dry gas position increased to 146,000 net acres and 9.5 Tcf of
    net resource

Antero Resources (NYSE: AR) ("Antero" or the "Company") today announced that
proved reserves at June 30, 2014 were 9.1 Tcfe, a 19% increase compared to
proved reserves at December 31, 2013, in each case assuming ethane rejection.
Proved, probable and possible ("3P") reserves at June 30, 2014 totaled 37.5
Tcfe, which represents a 7% increase compared to December 31, 2013, assuming
ethane rejection. Antero's June 30, 2014 proved and 3P reserves excluded 356
and 1,425 million barrels of ethane, respectively, due to the relationship
between assumed ethane and natural gas prices which indicate ethane will be
rejected as of June 30, 2014. The Company's proved and 3P reserves also
excluded any reserves attributable to the Utica dry gas resource in West
Virginia or Pennsylvania.

Antero Resources logo.

Antero's reserves at June 30, 2014 were prepared by its internal reserve
engineers and have not been reviewed or audited by its independent reserve
engineers. 

Proved Reserves

As of June 30, 2014, proved reserves increased by 19% from year-end 2013 to
9.1 Tcfe, of which 87% were natural gas, 12% were natural gas liquids ("NGLs")
and 1% was oil. The Marcellus Shale accounted for 94% of proved reserves and
the Utica Shale accounted for the remaining 6%. Of the 1.5 Tcfe of proved
reserves added in the six months ended June 30, 2014, 1.3 Tcfe was attributed
to the Marcellus Shale. NGLs and oil increased by 49 million barrels and 6
million barrels, respectively, due to Antero's drilling program targeting
liquids-rich locations in the Marcellus and Utica Shale plays. Positive
performance revisions of 85 Bcfe were primarily due to improved Marcellus well
performance from shorter stage length ("SSL") completions offset by the
reclassification of 23 dry gas locations, representing 199 Bcfe, from proved
undeveloped to the probable category due to the SEC's five-year development
rule.

Approximately 26% of Antero's 488,000 net acres of current leasehold in the
Marcellus and Utica were classified as proved at June 30, 2014. Based on
Antero's successful drilling results to date, as well as those of other
operators in the vicinity of Antero's leasehold, the Company believes that a
substantial portion of its Marcellus and Utica Shale acreage will be added to
proved reserves over time as more wells are drilled. Antero's estimated
Marcellus and Utica proved reserves and undeveloped locations are primarily
booked assuming 660 foot and 1,000 foot interlateral distance, respectively.

Proved developed reserves increased 37% from year-end 2013 to 2.8 Tcfe at June
30, 2014. The Company added 59 Marcellus wells to proved developed reserves
in the six months ended June 30, 2014. Virtually all of the wells utilized
SSL completions and had an average estimated ultimate recovery ("EUR") of 1.9
Bcfe/1,000 feet of lateral (12% liquids) which is consistent with previous
estimates. Out of the 689 gross proved undeveloped Marcellus locations, 251,
or 36% of the total, are booked assuming SSL completions.

Antero added 22 Utica wells to proved developed reserves in the six months
ended June 30, 2014, consisting of 4 rich gas (1100-1200 Btu), 2 highly-rich
gas (1200 to 1225 Btu), 3 highly-rich gas/condensate (1225 to 1250 Btu) and 13
condensate (1250 to 1300 Btu) wells. The wells located in the rich gas and
highly-rich gas regimes had an average EUR of 2.6 Bcfe/1,000 feet of lateral
(14% liquids) and 2.8 Bcfe/1,000 feet of lateral (21% liquids), respectively.
The wells located in the highly-rich gas/condensate and condensate regimes had
an average EUR of 1.9 Bcfe/1,000 feet of lateral (26% liquids) and 1.1
Bcfe/1,000 feet of lateral (35% liquids), respectively. These EURs are
consistent with previous estimates.

The percentage of proved reserves classified as proved developed increased to
30% at June 30, 2014 as compared to 27% at year-end 2013. Proved undeveloped
reserves increased by 13%, primarily as a result of the successful execution
of Antero's Marcellus Shale development drilling plan. Antero's 6.3 Tcfe of
proved undeveloped reserves will require an estimated $5.8 billion of
development capital over the next five years, resulting in an estimated
average development cost for proved undeveloped reserves of $0.92 per Mcfe.

SEC prices for reserves were calculated as of June 30, 2014 on a weighted
average Appalachian index basis and were $88.82 per Bbl for oil and $3.95 per
MMBtu for natural gas. Using SEC prices, the pre-tax present value discounted
at 10% ("pre-tax PV10") of the June 30, 2014 proved reserves was $8.5 billion,
excluding the value of the Company's natural gas and oil hedges. Including
the value of Antero's hedges as of June 30, 2014 and using SEC prices, the
pre-tax PV10 value of proved reserves was $9.0 billion, a 28% increase over
year-end 2013. The pre-tax PV10 value of proved developed reserves was $4.4
billion excluding the value of hedges and $4.9 billion including the value of
hedges, a 41% increase over year-end 2013.



Summary of Changes in Proved Reserves (in Bcfe)
Balance at December 31, 2013                    7,632
Extensions, discoveries and additions           1,531
Performance revisions                           85
Price revisions                                 11
Estimated Production                            (152)
Balance at June 30, 2014                        9,107

3P Reserves

As of June 30, 2014, 3P reserves increased by 7% from year-end 2013 to 37.5
Tcfe, of which 85% were natural gas, 14% were NGLs and 1% was oil. The
Marcellus, Utica, and Upper Devonian Shale comprised 26.4 Tcfe, 6.4 Tcfe and
4.7 Tcfe of the 3P reserves, respectively. The 7% increase in 3P reserves was
driven primarily by the leasehold addition of 22,000 net acres in the
Marcellus Shale core in northern West Virginia and 13,000 net acres in the
Utica Shale core in southern Ohio, including 6,363 net acres associated with
Antero's previously announced Piedmont Lake lease acquisition.

Based on the results from SSL completions, Antero has increased the number of
locations assuming SSL from 1,768 gross undeveloped 3P Marcellus locations to
1,893 gross undeveloped 3P Marcellus locations, or 62% of the 3,057 total
gross undeveloped 3P Marcellus locations. Importantly, 25.5 Tcfe of Antero's
26.4 Tcfe 3P reserves in the Marcellus, or 97%, were classified as proved or
probable (2P), reflecting Antero's extensive delineation and development
activities in the Marcellus Shale.

Using SEC prices, the pre-tax PV10 of the June 30, 2014 3P reserves was $25.9
billion, excluding the value of the Company's natural gas and oil hedges.
This represents a 27% increase from the pre-tax PV10 of the year-end 2013 3P
reserves. Including the value of Antero's hedges as of June 30, 2014 and
using SEC prices, the pre-tax PV10 value of 3P reserves was $26.4 billion, a
24% increase over the pre-tax PV10 of the year-end 2013 3P reserves including
Antero's hedges.

The table below summarizes Antero's estimated reserve volumes using SEC
pricing, broken out by operating area.

              Marcellus Shale                  Utica Shale
              Gas    Liquids Total  Gross      Gas    Liquids Total  Gross
              (Bcf)  (MMBoe) (Bcfe) Locations  (Bcf)  (MMBoe) (Bcfe) Locations
Proved        7,454  179     8,530  990        406    22      537    78
Probable      13,486 581     16,969 2,193      2,844  78      3,315  445
Possible      824    15      913    175        2,313  42      2,568  353
Total 3P      21,764 775     26,412 3,358      5,563  143     6,419  876
3P PV10 ($Bn)                $19.4                            $6.5
% Liquids (1)                18%                              13%
              Upper Devonian Shale             Combined Total
              Gas    Liquids Total  Gross      Gas    Liquids Total  Gross
              (Bcf)  (MMBoe) (Bcfe) Locations  (Bcf)  (MMBoe) (Bcfe) Locations
Proved        40     0       40     9          7,900  201     9,107  1,077
Probable      811    1       816    184        17,141 660     21,100 2,822
Possible      3,502  48      3,788  928        6,640  105     7,269  1,456
Total 3P      4,353  49      4,645  1,121      31,680 966     37,476 5,355
3P PV10 ($Bn)                $0.0                             $26.4
(2)
% Liquids (1)                6%                               15%

    Represents liquids volumes as a % of total 3P volumes. Combined total
(1) liquids comprised of 880 million barrels of NGLs and 86 million barrels of
    oil.
(2) Total PV10 includes $508 million value of Antero hedges at June 30, 2014
    SEC pricing.

West Virginia and Pennsylvania Utica Shale Resource

Antero has Utica Shale dry gas rights on approximately 146,000 net acres of
its West Virginia and Pennsylvania Marcellus acreage position and has
identified 1,359 gross undeveloped locations with a total net resource of 9.5
Tcfe. Antero expects to drill and complete an exploratory Utica Shale dry gas
well in the second half of 2014.

Non-GAAP Disclosure

Pre-tax PV10 value is a non-GAAP financial measure as defined by the SEC.
Antero believes that the presentation of pre-tax PV10 value is relevant and
useful to the Company's investors because it presents the discounted future
net cash flows attributable to Antero's reserves prior to taking into account
corporate future income taxes and the Company's current tax structure. Antero
further believes investors and creditors use pre-tax PV10 value as a basis for
comparison of the relative size and value of Antero's reserves as compared
with other companies. With respect to PV10 calculated as of an interim date,
it is not practical to calculate the taxes for the related interim period
because GAAP does not provide for disclosure of standardized measure on an
interim basis.

Antero Resources is an independent oil and natural gas company engaged in the
acquisition, development and production of unconventional oil and liquids-rich
natural gas properties primarily located in the Appalachian Basin in West
Virginia, Ohio and Pennsylvania. Antero's website is located at
www.anteroresources.com.

Cautionary Statements

This release includes "forward-looking statements". Such forward-looking
statements are subject to a number of risks and uncertainties, many of which
are beyond Antero's control. All statements, other than historical facts
included in this release, are forward-looking statements. All forward-looking
statements speak only as of the date of this release. Although Antero 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.

Antero cautions you that these forward-looking statements are subject to all
of the risks and uncertainties, most of which are difficult to predict and
many of which are beyond the Company's control, incident to the exploration
for and development, production, gathering and sale of natural gas, NGLs and
oil. 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's Annual Report on Form 10-K for
the year ended December 31, 2013.

The SEC permits oil and gas companies to disclose probable and possible
reserves in their filings with the SEC. Antero does not plan to include
probable and possible reserve estimates in its filings with the SEC. Antero
has provided internally generated estimates that have not been reviewed or
audited by its third party reserve engineer in this release. Antero's
estimate of proved, probable and possible reserves is provided in this release
because management believes it is useful information that is widely used by
the investment community in the valuation, comparison and analysis of
companies. However, the Company notes that the SEC prohibits companies from
aggregating proved, probable and possible reserves in filings with the SEC due
to the different levels of certainty associated with each reserve category.

"EUR," or Estimated Ultimate Recovery, refers to Antero's internal estimates
of per well hydrocarbon quantities that may be potentially recovered from a
hypothetical future well completed as a producer in the area. These quantities
do not necessarily constitute or represent reserves within the meaning of the
Society of Petroleum Engineer's Petroleum Resource Management System or the
SEC's oil and natural gas disclosure rules.

Estimates of Antero's net resource have been prepared by its internal reserve
engineers and management without review by independent engineers. These
estimates by their nature are more speculative than estimates of proved,
probable, and possible reserves and accordingly are subject to substantially
greater risk of being actually realized. Antero includes these estimates to
demonstrate what it believes to be the potential for future drilling and
production by the company. Ultimate recoveries will be dependent upon numerous
factors including actual encountered geological conditions, the impact of
future oil and gas pricing, exploration and development costs, and Antero's
future drilling decisions and budgets based upon its future evaluation of
risk, returns and the availability of capital and, in many areas, the outcome
of negotiation of drilling arrangements with holders of adjacent or fractional
interest leases. Estimates of net resource and other figures may change
significantly as development of Antero's resource plays provide additional
data and therefore actual quantities that may ultimately be recovered will
likely differ materially from these estimates."

This release provides a summary of Antero's reserves as of June 30, 2014,
assuming ethane "rejection". Ethane rejection occurs when ethane is left in
the wellhead natural gas stream when the natural gas is processed, rather than
being separated out and sold as a liquid after fractionation. When ethane is
left in the gas stream, the Btu content of the residue natural gas at the
outlet of the processing plant is higher. Producers will generally elect to
"reject" ethane at the processing plant when the price received for the ethane
in the natural gas stream is greater than the price received for the ethane
being sold as a liquid after fractionation, net of fractionation costs. When
ethane is recovered in the processing plant, the Btu content of the residue
natural gas is lower, but a producer is then able to recover the value of the
ethane sold as a separate natural gas liquid product. In addition, natural
gas processing plants can produce the other NGL products (propane, normal
butane, isobutene and natural gasoline) while rejecting ethane.

Logo - http://photos.prnewswire.com/prnh/20131101/LA09101LOGO

SOURCE Antero Resources

Website: http://www.anteroresources.com
Contact: Michael Kennedy, VP Finance, (303) 357-6782 or
mkennedy@anteroresources.com.
 
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