CONSOL Energy Announces Operations Update

                  CONSOL Energy Announces Operations Update

Gas Division Announces Upper Devonian Shale Exploration Success;

Gas Division Initiates 2014 Production Guidance of 210 - 225 Bcfe;

Coal Division Produces 13.8 Million Tons in Quarter

PR Newswire

PITTSBURGH, July 15, 2013

PITTSBURGH, July 15, 2013 /PRNewswire/ -- CONSOL Energy Inc. (NYSE: CNX), the
leading diversified fuel producer in the Eastern U.S., is providing an
operations update for the quarter ended June 30, 2013.

"Our operations performed in line this quarter," commented J. Brett Harvey,
chairman and chief executive officer. "In our Gas Division, we drilled a
successful Upper Devonian Shale exploration well on our first attempt."

Specifically, CONSOL Energy drilled its Upper Devonian Shale well in the
Burkett formation, which is the deepest of numerous Upper Devonian shales. The
Burkett formation is the only Upper Devonian shale which falls within the
ownership of the joint venture with Noble Energy. CONSOL chose to drill its
first well in the Burkett in order to test the potential interaction with
deeper Marcellus Shale wells and to benefit from jointly-owned surface
infrastructure. CONSOL's future Upper Devonian Shale wells will include wells
drilled in 100% CONSOL-owned strata.

The company believes that while all of its acreage in Southwestern Pa. and
Northern W.Va. has the potential for the existence of the Upper Devonian Shale
formation, our initial geologic estimates show that we control 300,000 acres
with commercial Upper Devonian Shale potential.

The company's first Upper Devonian Shale well, the NV 39F, is located in
Greene County, Pa. The joint venture well had an average casing pressure of
2,173 psi on a 42/64 inch choke and was drilled to a total measured depth of
12,490 feet, with a lateral length of 4,889 feet. The well was completed in 17
stages. The well was fractured together with five underlying Marcellus Shale
wells and has been flowing at a sustained rate of approximately 3.0 MMcfd.
Importantly, the NV 39F well seems to have concentrated and contained the
fracture treatments in the Marcellus Shale wells below; specifically, the NV
39B and NV 39C Marcellus Shale wells, which are showing strong early results
flowing at approximately 9.0 MMcfd and 10.0 MMcfd, respectively.

Overall, CONSOL's Gas Division produced 38.6 Bcfe for the 2013 second quarter
or 3% more than the 37.3 Bcfe produced in the 2012 second quarter, which is
consistent with guidance provided last quarter. The 2013 second quarter
production included 418 MMcf per day of natural gas, 335 barrels per day of
oil/condensates, and 655 barrels per day of NGLs (all net to CONSOL). As we
expected, our 2013 well completions will be weighted toward the back-end of
the year.

CONSOL's Coal Division produced 13.8 million tons for the second quarter of
2013, including 1.2 million tons of low-vol coking coal from the company's
Buchanan Mine. Both production figures were slightly above previous guidance
provided last quarter. Although second quarter sales at Buchanan were higher
than expected, low-vol prices weakened as the quarter progressed.

During the second quarter of 2013, CONSOL's total coal inventory decreased by
47,000 tons to 917,000 tons as of June 30, 2013, which marks a new 15-year low
inventory level. Thermal coal inventory decreased by 102,000 tons to 773,000
tons during the quarter, as customers continued to take all contracted
tonnage. Low-vol coal inventory increased during the quarter by 55,000 tons,
to 144,000 tons.

Third Quarter 2013 Forecasts

Gas: CONSOL Energy expects its 2013 gas production to be approximately 170 –
175 Bcfe (net to CONSOL). Third quarter 2013 gas production, net to CONSOL, is
expected to be approximately 43 – 45 Bcfe, which is an estimated 14% increase
compared with the 38.6 Bcfe produced in the second quarter of 2013, based on
the midpoint of the range.

Coal: CONSOL Energy expects third quarter 2013 total coal production to be
between 13.4 – 13.9 million tons. Annual 2013 total coal production guidance
is 55.5 – 57.5 million tons. Buchanan Mine's third quarter production is
expected to be between 0.7 – 0.9 million tons, while annual production
guidance remains at 4.0 – 4.2 million tons.

2014 Gas Forecast

CONSOL Energy is initiating a 2014 production estimate of 210 – 225 Bcfe.
Although early in the planning process, the company believes 225 Bcfe is a
reasonable upper bound, given the level of drilling in 2013 and the expected
effect that could have on 2014 production.

"Despite the uncertainty surrounding the upper bound of our initial 2014 gas
production guidance," continued Mr. Harvey, "Investors need to understand that
CONSOL's 2013 investment in gas will have an important effect on our 2014 gas
production. The Gas Division represents the growth vehicle for CONSOL's
shareholders once the BMX Mine is completed next year."

And, that rate of growth is expected to accelerate. Assuming the company
achieves the mid-point of the 2013 guidance range of 172.5 Bcfe, it would
represent a 10% growth rate over 2012 actual production of 156.3 Bcfe. For
2014, the range of 210 – 225 Bcfe represents a 22% - 30% growth rate over the
172.5 Bcfe our 2013 forecast.

Furthermore, the company expects to achieve Gas Division margin expansion
through the increased emphasis on production in the liquids-rich portions of
the Marcellus and Utica shales. Condensates and NGLs typically generate much
higher revenues than methane on an equivalent units basis. Our 2013 exit rate
is projected to be 520 barrels per day of oil/condensates and 4,900 barrels
per day of NGLs, with higher levels expected in 2014.

"When you look back over the last few years," continued Mr. Harvey, "CONSOL
bought an opportunity in 2010 with the Marcellus and Utica shale acreage we
acquired from Dominion E&P. Then, in 2011, we brought in top-quality joint
venture partners to bring value forward for our shareholders. In 2012, our
joint ventures began producing in the liquids-rich area of the plays. And
today, we're adding rigs and accelerating our drilling. I see 2014 as a
logical progression in this endeavor, where we'll be able to continue our
acceleration in gas production and deliver meaningful value to our
shareholders. And unlike pure-play E&P companies, we'll have a Coal Division
and potential asset sales that can help fund this growth."

Gas Division Operations

CONSOL's Gas Division saw zero safety exceptions in the first quarter of 2013,
which is unchanged compared to the same quarter of 2012. In the area of
compliance, CONSOL's Gas Division saw violations decrease by 40% compared to
the year-earlier quarter.

During the second quarter, CONSOL Energy drilled 13 horizontal shale wells:
nine Marcellus Shale and four Utica Shale wells. The average drilled lateral
length for the Marcellus Shale wells and the Utica Shale wells was 8,860 feet
and 5,459 feet, respectively. CONSOL completed 15 Marcellus Shale wells in the
second quarter and expects to initiate completion operations on the Utica
Shale wells in the third quarter of 2013.  

Marcellus Shale Dry Gas (CONSOL Energy-operated):

Southwest Pa.: During the second quarter, CONSOL drilled six wells in
Southwest Pa., all in Washington County. The wells ranged in lateral length
from 7,274 feet to 10,171 feet.

CONSOL completed 10 wells: six wells in Washington County and four wells in
Greene County. Also during the second quarter, CONSOL turned in line 14 wells:
three wells of the five-well NV 42 pad, the eight-well NV 41 pad, and three
wells of the six-well NV 39 pad, which are currently producing approximately
17.0 MMcfd, 36.0 MMcfd, and 14.8 MMcfd, respectively.

CONSOL has one horizontal rig operating and plans to drill an additional nine
wells in Southwest Pa., which is a slight decrease from previous guidance
provided last quarter to now drill 22 wells in 2013.

Central Pa.: During the second quarter, CONSOL did not drill any new wells in
Central Pa.

CONSOL completed five wells located on the Kuhn 3 pad in Westmoreland County,
and flowback operations have commenced. One well, the Kuhn 3B, has been turned
in line, where it subsequently flowed at 10 MMcf during a 24-hour period.

CONSOL does not currently have a horizontal rig operating but expects to drill
five additional wells in Westmoreland County in Central Pa., which increases
previous guidance provided last quarter to now drill 10 wells in 2013. 

Northern W.Va.: During the second quarter, CONSOL drilled the first three of
six wells on the PHL 13 pad in the Philippi Field, Barbour County. The wells
ranged in lateral length from 7,586 feet to 9,974 feet.

CONSOL expects completion operations to commence on the PHL 13 wells in
September 2013.

CONSOL has one horizontal rig operating in Barbour County and expects to drill
eight additional wells in Northern W.Va., which is an increase from previous
guidance provided last quarter to now drill 11 wells in 2013.

Marcellus Shale Wet Gas (Noble Energy-operated):

During the second quarter, in the wet gas portion of the Marcellus Shale,
Noble Energy drilled 13 wells: eight wells in Marshall County, W.Va. and five
wells in Gilmer County, W.Va. The wells ranged in lateral length from 3,255
feet to 8,858 feet.

Noble Energy completed, and turned in line, 11 wells on the WEB 4 pad located
in Marshall County, W.Va.

Noble Energy is currently operating three horizontal rigs with the addition of
a fourth rig now expected in the third quarter. By the end of 2013, Noble
expects to operate five horizontal rigs, which is a decrease from previous
guidance provided last quarter of six rigs, due to the improvements in
horizontal rig efficiency being realized by increased top-hole drilling.

Ohio Utica Shale (CONSOL-operated):

During the second quarter, in the Utica Shale joint venture with Hess
Corporation, CONSOL Energy drilled four wells: the third and final well on the
NBL 11 pad, and three wells on the NBL 33 pad, all in Noble County. The
average lateral length of the NBL 11 pad and the NBL 33 pad was 5,801 feet and
5,476 feet, respectively.

CONSOL expects completion operations on all six wells to commence in the third
quarter. CONSOL expects production from the NBL 11 and NBL 33 wells, as well
as the previously drilled NBL 1A and NBL 16A wells, to commence by the end of
2013 or very early in 2014.

CONSOL has one horizontal rig operating and expects to drill three additional
wells in Noble County, which is a slight decrease from previous guidance
provided last quarter to now drill nine wells in 2013, all in Noble County.

Ohio Utica Shale (Hess-operated):

During the second quarter, our joint venture partner, Hess Corporation,
drilled four wells: the Athens A 2H-24 and Athens A 3H-24 wells in Harrison
County; and the Oxford A 1H-8 and Oxford A 2H-8 wells in Guernsey County.

Hess completed two wells: the Athens A 2H-24 and Athens A 3H-24 wells during
the second quarter. 

Hess finished the second quarter with two horizontal rigs operating on JV
acreage. Their current activity level is consistent with guidance provided by
them last quarter.

Coal Division Operations

CONSOL's Coal Division saw safety exceptions flat in the second quarter of
2013 compared to the same quarter of 2012. In the area of compliance, CONSOL's
Coal Division saw violations decrease by 16% compared to the year-earlier

The Bailey Preparation Plant has successfully upgraded the existing control
room with new computers, operator screens, and the required software and
hardware to support the increased plant capacity from 6,300 tons per hour
(tph) to 8,200 tph. Also, the Bailey clean coal handling system installed, and
placed into operation, a new dual batch loadout facility that will increase
the capacity of loading unit trains to 9,000 tph, which is a 50% increase from
the previous unit that had a loading capacity of approximately 6,000 tph.
These continuous improvement projects are in anticipation of starting
production at the BMX Mine on April 1, 2014.

Earnings Release Information

CONSOL Energy will report additional operational and financial results for the
quarter ended June 30, 2013 at 7:00 a.m. ET on Thursday, July 25, followed by
a conference call at 10:00 a.m. ET. The call can be accessed at the investor
relations section of the company's web site, at

Cautionary Statements

Various statements in this release, including those that express a belief,
expectation or intention, may be considered forward-looking statements (as
defined in Section 21E of the Exchange Act) that involve risks and
uncertainties that could cause actual results to differ materially from
projected results. Accordingly, investors should not place undue reliance on
forward-looking statements as a prediction of actual results. The
forward-looking statements may include projections and estimates concerning
the timing and success of specific projects and our future production,
revenues, income and capital spending. When we use the words "believe,"
"intend," "expect," "may," "should," "anticipate," "could," "estimate,"
"plan," "predict," "project," or their negatives, or other similar
expressions, the statements which include those words are usually
forward-looking statements. When we describe strategy that involves risks or
uncertainties, we are making forward-looking statements. The forward-looking
statements in this press release, if any, speak only as of the date of this
press release; we disclaim any obligation to update these statements. We have
based these forward-looking statements on our current expectations and
assumptions about future events. While our management considers these
expectations and assumptions to be reasonable, they are inherently subject to
significant business, economic, competitive, regulatory and other risks,
contingencies and uncertainties, most of which are difficult to predict and
many of which are beyond our control. These risks, contingencies and
uncertainties relate to, among other matters, the following: deterioration in
global economic conditions in any of the industries in which our customers
operate, or sustained uncertainty in financial markets cause conditions we
cannot predict; an extended decline in demand for or in the prices we receive
for our coal and gas affecting our operating results and cash flows; our
customers extending existing contracts or entering into new long-term
contracts for coal; the expiration or failure to extend existing long-term
contracts; our reliance on major customers; our inability to collect payments
from customers if their creditworthiness declines; the disruption of rail,
barge, gathering, processing and transportation facilities and other systems
that deliver our coal and gas to market; a loss of our competitive position
because of the competitive nature of the coal and gas industries, or a loss of
our competitive position because of overcapacity in these industries impairing
our profitability; our failure to maintain satisfactory labor relations; coal
users switching to other fuels in order to comply with various environmental
standards related to coal combustion emissions; the impact of potential, as
well as any adopted regulations relating to greenhouse gas emissions on the
demand for coal and natural gas, as well as the impact of any adopted
regulations on our coal mining operations due to the venting of coalbed
methane which occurs during mining; foreign currency fluctuations could
adversely affect the competitiveness of our coal abroad; the risks inherent in
coal and gas operations being subject to unexpected disruptions, including
geological conditions, equipment failure, timing of completion of significant
construction or repair of equipment, fires, explosions, accidents and weather
conditions which could impact financial results; our focus on new gas
development projects and exploration for gas in areas where we have little or
no proven gas reserves; decreases in the availability of, or increases in, the
price of commodities and services used in our mining and gas operations, as
well as our exposure under "take or pay" contracts we entered into with well
service providers to obtain services of which if not used could impact our
cost of production; obtaining, maintaining and renewing governmental permits
and approvals for our coal and gas operations; the effects of government
regulation on the discharge into the water or air, and the disposal and
clean-up of, hazardous substances and wastes generated during our coal and gas
operations; the effects of stringent federal and state employee health and
safety regulations, including the ability of regulators to shut down a mine or
well; the potential for liabilities arising from environmental contamination
or alleged environmental contamination in connection with our past or current
coal and gas operations; the effects of mine closing, reclamation, gas well
closing and certain other liabilities; uncertainties in estimating our
economically recoverable coal and gas reserves; defects may exist in our chain
of title and we may incur additional costs associated with perfecting title
for coal or gas rights on some of our properties or failing to acquire these
additional rights we may have to reduce our estimated reserves; the outcomes
of various legal proceedings, which are more fully described in our reports
filed under the Securities Exchange Act of 1934; the impacts of various
asbestos litigation claims; increased exposure to employee related long-term
liabilities; increased exposure to multi-employer pension plan liabilities;
minimum funding requirements by the Pension Protection Act of 2006 (the
Pension Act) coupled with the significant investment and plan asset losses
suffered during the recent economic decline has exposed us to making
additional required cash contributions to fund the pension benefit plans which
we sponsor and the multi-employer pension benefit plans in which we
participate; lump sum payments made to retiring salaried employees pursuant to
our defined benefit pension plan exceeding total service and interest cost in
a plan year; acquisitions and joint ventures that we recently have completed
or entered into or may make in the future including the accuracy of our
assessment of the acquired businesses and their risks, achieving any
anticipated synergies, integrating the acquisitions and unanticipated changes
that could affect assumptions we may have made and divestitures we anticipate
may not occur or produce anticipated proceeds including joint venture partners
paying anticipated carry obligations; the anti-takeover effects of our rights
plan could prevent a change of control; increased exposure on our financial
performance due to the degree we are leveraged; replacing our natural gas
reserves, which if not replaced, will cause our gas reserves and gas
production to decline; our ability to acquire water supplies needed for gas
drilling, or our ability to dispose of water used or removed from strata in
connection with our gas operations at a reasonable cost and within applicable
environmental rules; our hedging activities may prevent us from benefiting
from price increases and may expose us to other risks; changes in federal or
state income tax laws, particularly in the area of percentage depletion and
intangible drilling costs, could cause our financial position and
profitability to deteriorate; and other factors discussed in the 2012 Form
10-K under "Risk Factors," as updated by any subsequent Form 10-Qs, which are
on file at the Securities and Exchange Commission.

The SEC permits oil and gas companies, in their filings with the SEC, to
disclose only proved, probable and possible oil and gas reserves that a
company anticipates as of a given date to be economically and legally
producible and deliverable by application of development projects to known
accumulations. We may use certain terms in this press release, such as EUR
(estimated ultimate recovery), unproved reserves and total resource potential,
that the SEC's rules strictly prohibit us from including in filings with the
SEC. These measures are by their nature more speculative than estimates of
reserves prepared in accordance with SEC definitions and guidelines and
accordingly are less certain. We also note that the SEC strictly prohibits us
from aggregating proved, probable and possible reserves in filings with the
SEC due to the different levels of certainty associated with each reserve


Contact: Investor: Dan Zajdel at (724) 485-4169; Tyler Lewis at (724)
485-3157, Media: Lynn Seay at (724) 485-4065
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