Market Overview

Eclipse Resources Corporation Announces Second Quarter 2017 Results, a $325 Million Utica Shale Drilling Joint Venture Commitment Agreement and an Increase in the Company's Borrowing Base

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Eclipse Resources Corporation (NYSE:ECR) (the "Company" or "Eclipse
Resources") today announced its second quarter 2017 financial and
operational results, along with updated guidance for the third quarter
of 2017 and full year 2017. As discussed further below the Company has
also entered into a commitment agreement with Sequel Energy Group LLC
("Sequel") (an affiliate of GSO Capital Partners, or "GSO") to establish
a proposed drilling joint venture and has received an increase to its
borrowing base on its senior secured revolving line of credit from its
bank-lending group. In conjunction with this release, the Company has
posted an updated investor presentation to its website at www.eclipseresources.com.

Second Quarter 2017 Highlights:

  • Average net daily production was 287.8 MMcfe per day, exceeding the
    high end of the Company's previously issued production guidance range
    of 265 to 275 MMcfe per day.
  • Realized an average natural gas price, before the impact of cash
    settled derivatives and firm transportation expenses, of $2.98 per
    Mcf, a $0.20 per Mcf discount to the average monthly NYMEX settled
    natural gas price during the quarter.
  • Realized an average oil price, before the impact of cash settled
    derivatives, of $43.57 per barrel, a $4.53 per barrel discount to the
    average WTI oil price during the quarter, exceeding the Company's
    previously issued oil differential guidance range of $7.50 to $8.50
    per barrel.
  • Realized an average natural gas liquids ("NGL") price, before the
    impact of cash settled derivatives, of $16.84 per barrel, or
    approximately 35% of the average WTI oil price during the quarter.
  • Per unit cash production costs (including lease operating,
    transportation, gathering and compression, production and ad valorem
    taxes) were $1.36 per Mcfe and include $0.35 per Mcfe in
    firm transportation expenses, which was below the Company's previously
    issued per unit cash production cost guidance range of $1.45 to $1.50
    per Mcfe.
  • Net income for the second quarter of 2017 was $11.5 million; and
    Adjusted EBITDAX1 for the second quarter of 2017 was $39.6
    million.

Subsequent to the end of the Second Quarter:

  • The Company has entered into a commitment agreement with Sequel to
    establish a drilling joint venture on the Company's Utica Shale
    acreage in southeast Ohio. Eclipse and Sequel expect to enter into
    definitive documents relating to the proposed transaction by the end
    of the current quarter.
    • The commitment agreement sets forth the proposed terms for the
      drilling joint venture, including:
      • Committed funding from Sequel of up to $325 million to fund
        its proportionate share of two drilling programs comprising 34
        gross wells in aggregate, commencing with wells currently in
        progress and extending through wells expected to be commenced
        through the end 2018.
      • A mutual option for an additional third well program of
        similar size, which would increase the committed funding.
      • Eclipse Resources shall be the operator of all wells drilled
        within each well program.
      • Eclipse Resources shall have the right to adjust its pre-carry
        working interest in the first program up until the fourth
        quarter of 2017 to between 30% to 50%, and its pre-carry
        working interest in the second program to between 30% to 70%
        until such program is commenced.
      • A 15% carried interest on drilling and completion capital
        expenditures incurred in each well program, proportionately
        reduced to Eclipse Resources retained pre-carry working
        interest.
      • A significant portion of Sequel's working interest in each
        well program will revert to Eclipse Resources once a certain
        return is realized by Sequel in each program.

      The Company's proposed drilling joint venture with Sequel is
      subject to further negotiation, completion and execution of
      definitive agreements and other customary conditions. The
      commitment agreement provides that Eclipse and Sequel will
      negotiate in good faith for a period of time and use their
      commercially reasonable efforts to enter into mutually agreeable
      definitive documents relating to the proposed transaction, which
      the parties expect to complete by the end of the current quarter
      .
      Accordingly, there can be no assurance that the proposed
      transaction will be completed in the anticipated timeframe, if
      at all, and if consummated, what will be the final terms of such
      definitive agreement.

  • The Company has recently completed its semi-annual borrowing base
    redetermination of its revolving credit facility, which resulted in an
    increase in its borrowing base from $175 million to $225 million. The
    Company remains undrawn under its revolving credit facility, other
    than letters of credit associated with its firm natural gas
    transportation agreements.
  • The Company added to its 2018 oil hedge portfolio by executing
    incremental three way collars of 4,000 barrels per day at an average
    floor price2 of $45.00 and an average ceiling price of
    $52.26.

1 Non-GAAP measure. See reconciliation for details.

2 For the purposes of calculating three-way floor
price, the higher valued put is used.

Benjamin W. Hulburt, Chairman, President and CEO, commented on the
Company's second quarter 2017 results, "Our continued focus on
execution, innovation and efficiency resulted in the Company delivering
another tremendous quarter with production above the top end of our
guidance, operating expenses below the low end of our guidance and
continued strong well performance in both the dry gas and condensate
areas of our acreage. This now marks the eleventh consecutive reporting
period in which the Company has met or exceeded its production and
operating expense guidance, which represents every single reporting
period since our initial public offering in June of 2014.

We continue to strive to be a leader in innovation, not only in our
region, but nationwide, with a significant amount of work we are doing
today focused on new technology applications to improve productivity,
reduce costs and maintain high returning wells as we develop our
substantial drilling inventory. This culture of innovation powers our
well performance and we have seen that illustrated in our most recent
set of Dry Gas wells. These wells have incorporated a series of trials
on numerous new techniques that will help us develop our "Gen4" well
design. Our seven well Moser pad, located in the Company's Dry Gas
acreage in eastern Monroe County, Ohio, was turned to sales in June and
has produced at an average rate of approximately 19% above our recently
increased Dry Gas type well expectation. We are continuing to evaluate
which of the new techniques may be the most impactful on future
operations, but we are very encouraged with the results we are seeing on
certain of the techniques we've tested.

We have continued our relentless pursuit for industry leading drilling
innovation, and have set a new internal record on our most recent
"super-lateral", which we drilled to a total measured depth of 24,600
with a 15,600 foot completable lateral in our Utica Condensate area in
12 days from spud to TD. Additionally, we are currently completing what
we believe to be the longest onshore laterals ever drilled, the Great
Scott 3H (19,100' completable lateral) and Outlaw C11H (19,500'
completable lateral), located in our Utica Condensate area. We are
approximately 70% done completing these laterals, which have treated as
designed thus far. We have two additional wells to complete on this pad
before we will turn all four wells to sales, which we expect to occur in
the fourth quarter of 2017.

We believe that the drilling joint venture commitment agreement we have
recently entered into with Sequel, an affiliate of GSO, speaks to both
the quality of our assets and our industry leading operational
performance. At today's forward strip prices, Eclipse calculates that
the present value of the carried interest and significant working
interest reversion as outlined in the commitment agreement will equate
to a meaningful valuation premium to both where we trade and where
recent Utica asset transactions have taken place. Perhaps most
importantly, as we see a significant amount of commodity volatility
looking into 2018, the terms of this drilling joint venture will allow
us to maintain, or even accelerate our current drilling pace, while
scaling our company level capital expenditures based on the economic
environment. Additionally, prior to commencing each well program, under
the terms proposed in the commitment agreement, Eclipse will have the
ability to choose its working interest for such program within agreed
upon bands. We believe this structure allows us to maintain an
efficient, two-rig operating program while providing flexibility to
manage capital spending to a level that is appropriate depending on the
strength of forward commodity curves. We are extremely pleased with the
proposed terms and structure as outlined by the commitment agreement
with Sequel and the high degree of confidence that our partner has in
our assets and operational capabilities. We believe that the industry
experience of the Sequel team combined with the scale and structuring
capabilities of GSO make them the ideal drilling joint venture partners
for Eclipse.

We believe that our proven operational performance, continued gain in
efficiency and financial flexibility leave us well positioned to deliver
upon the production guidance that we have provided. We remain highly
focused on returns and excited for continued operational improvement. We
believe that these attributes will drive significant value enhancements
from our assets and generate long-term shareholder value."

Operational Discussion

The Company's production for the three and six months ended June 30,
2017 and 2016 is set forth in the following table:

     
Three Months Ended Six Months Ended
June 30, June 30,
2017     2016 2017     2016
Production:        
Natural gas (MMcf) 20,127.8 15,298.5 39,509.4 28,985.8
NGL sales (Mbbls) 662.1 685.9 1,327.1 1,199.6
Oil sales (Mbbls) 347.8 345.2 801.9 600.5
Total (MMcfe) 26,187.2 21,485.1 52,283.4 39,786.4
 
Average daily production volume:
Natural gas (Mcf/d) 221,185 168,115 218,284 159,263
NGL sales (Bbls/d) 7,276 7,537 7,332 6,591
Oil sales (Bbls/d) 3,822 3,793 4,430 3,299
Total (Mcfe/d) 287,771 236,095 288,859 218,603
 

Market Conditions

Prices for various quantities of natural gas, NGLs and oil that we
produce significantly impact our revenues and cash flows. Prices for
commodities, such as hydrocarbons, are inherently volatile. The
following table lists average daily, high, low and average monthly
settled NYMEX Henry Hub prices for natural gas and NYMEX WTI prices for
oil for the three and six months ended June 30, 2017 and 2016:

     
Three Months Ended Six Months Ended
June 30, June 30,
2017     2016 2017     2016
NYMEX Henry Hub High ($/MMBtu) $ 3.27 $ 2.94 $ 3.71 $ 2.94
NYMEX Henry Hub Low ($/MMBtu) 2.85 1.71 2.44 1.49
Average Daily NYMEX Henry Hub ($/MMBtu) 3.08 2.16 3.05 2.09
Average Monthly NYMEX Settled Henry Hub ($/MMBtu) 3.18 1.95 3.25 2.02
 
NYMEX WTI High ($/Bbl) $ 53.38 $ 51.23 $ 54.48 $ 51.23
NYMEX WTI Low ($/Bbl) 42.48 34.30 42.48 26.19
Average NYMEX WTI ($/Bbl) 48.10 46.21 49.85 40.88
 

Financial Discussion

Revenue for the second quarter of 2017 totaled $86.2 million, compared
to $47.1 million for the second quarter of 2016. Adjusted Revenue3,
which includes the impact of cash settled derivatives and excludes
brokered natural gas and marketing revenue, totaled $83.6 million for
the second quarter of 2017 compared to $58.8 million for the second
quarter of 2016. Net Income (Loss) for the second quarter of 2017 was
$11.5 million, or $0.04 per share compared to $(73.2) million or $(0.33)
per share for the second quarter of 2016. Adjusted Net Income (Loss)
3
for the second quarter of 2017 was $(2.8) million, or $(0.01)
per share, compared to $(24.1) million, or $(0.11) per share for the
second quarter of 2016. Adjusted EBITDAX3 was $39.6 million
for the second quarter of 2017, compared to $16.9 million for the second
quarter of 2016.

Revenue for the six months ended June 30, 2017 totaled $188.1 million,
compared to $96.7 million for the six months ended June 30, 2016.
Adjusted Revenue3, which includes the impact of cash settled
derivatives and excludes brokered natural gas and marketing revenue,
totaled $179.0 million for the six months ended June 30, 2017 compared
to $117.6 million for the six months ended June 30, 2016. Net Income
(Loss) for the six months ended June 30, 2017 was $38.3 million, or
$0.15 per share compared to $(118.7) million or $(0.53) per share for
the six months ended June 30, 2016. Adjusted Net Income (Loss)3
for the six months ended June 30, 2017 was $2.1 million, or $0.01 per
share, compared to $(39.2) million, or $(0.18) per share for the six
months ended June 30, 2016. Adjusted EBITDAX3 was $89.8
million for the six months ended June 30, 2017, compared to $37.3
million for the six months ended June 30, 2016.

3 Adjusted Revenue, Adjusted Net Income (Loss) and
Adjusted EBITDAX are non-GAAP financial measures. Tables reconciling
Adjusted Revenue, Adjusted Net Income (Loss) and Adjusted EBITDAX to the
most directly comparable GAAP measures can be found at the end of the
financial statements included in this press release.

Average realized price calculations for the three and six months ended
June 30, 2017 and 2016 are set forth in the table below:

     
Three Months Ended Six Months Ended
June 30, June 30,
2017     2016 2017     2016
Average Sales Price (excluding cash settled derivatives

and firm transportation)

Natural gas ($/Mcf) $ 2.98 $ 1.56 $ 3.07 $ 1.79
NGLs ($/Bbl) 16.84 13.60 21.26 13.22
Oil ($/Bbl) 43.57 36.74 45.02 30.99
Total average prices ($/Mcfe) 3.29 2.14 3.55 2.17
 
Average Sales Price (including cash settled derivatives,

excluding firm transportation)

Natural gas ($/Mcf) $ 2.86 $ 2.31 $ 2.94 $ 2.60
NGLs ($/Bbl) 16.38 13.43 20.23 13.43
Oil ($/Bbl) 43.57 41.38 45.11 43.52
Total average prices ($/Mcfe) 3.19 2.74 3.42 2.96
 
Average Sales Price (including firm transportation,

excluding cash settled derivatives)

Natural gas ($/Mcf) $ 2.52 $ 1.12 $ 2.56 $ 1.35
NGLs ($/Bbl) 16.84 13.60 21.26 13.22
Oil ($/Bbl) 43.57 36.74 45.02 30.99
Total average prices ($/Mcfe) 2.94 1.82 3.16 1.85
 
Average Sales Price (including cash settled derivatives

and firm transportation)

Natural gas ($/Mcf) $ 2.41 $ 1.86 $ 2.43 $ 2.16
NGLs ($/Bbl) 16.38 13.43 20.23 13.43
Oil ($/Bbl) 43.57 41.38 45.11 43.52
Total average prices ($/Mcfe) 2.84 2.42 3.04 2.63
 

The Company's operating expenses per Mcfe for the second quarter of 2017
decreased by 8% compared to the prior year's quarter and are shown in
the table below. Per unit cash production costs (includes lease
operating, transportation, gathering and compression, production and ad
valorem taxes) were $1.36 per Mcfe for the second quarter 2017 and
includes $0.35 per Mcfe of firm transportation expenses.

     
Three Months Ended Six Months Ended
June 30, June 30,
2017     2016 2017     2016
Operating expenses (in thousands):
Lease operating $ 4,568 $ 2,248 $ 6,911 $ 4,925
Transportation, gathering and compression 28,969 28,254 61,846 51,391
Production and ad valorem taxes 2,033 2,203 3,964 4,766
Depreciation, depletion and amortization 25,152 20,949 51,341 36,062
General and administrative 10,730 10,402 20,862 21,676
Operating expenses per Mcfe:
Lease operating $ 0.17 $ 0.10 $ 0.13 $ 0.12
Transportation, gathering and compression 1.11 1.32 1.19 1.29
Production, severance and ad valorem taxes 0.08 0.10 0.08 0.12
Depreciation, depletion and amortization 0.96 0.98 0.98 0.91
General and administrative 0.41 0.48 0.40 0.54
 

Capital Expenditures

Second quarter 2017 capital expenditures were $98.5 million. These
expenditures included $80.2 million for drilling and completions, $0.7
million for midstream expenditures, $17.3 million for land-related
expenditures, and $0.3 million for corporate-related expenditures.

During the second quarter of 2017, the Company drilled 9 gross (8.6 net)
operated Utica Shale wells. In addition, the Company completed 6 gross
(5.8 net) operated wells and turned to sales 9 gross (9.0 net) operated
wells.

Financial Position and Liquidity

As of June 30, 2017, the Company's liquidity was $238.5 million,
consisting of $97.1 million in cash and cash equivalents and $141.4
million in available borrowing capacity under the Company's revolving
credit facility (after giving effect to outstanding letters of credit
issued by the Company of $33.6 million).

Subsequent to the end of the second quarter, 2017, the Company completed
its semi-annual borrowing base redetermination of its revolving credit
facility, which resulted in an increase in its borrowing base from $175
million to $225 million. The Company remains undrawn on its revolving
credit facility, other than for letters of credit.

Matthew R. DeNezza, Executive Vice President and Chief Financial
Officer, commented, "At quarter end and pro-forma for the recent
borrowing base redetermination, which resulted in a borrowing base
increase of approximately 29%, our liquidity would have been
approximately $288 million. We remain highly focused on the strength of
our balance sheet with the objective of keeping our leverage ratios low.
We believe this strong liquidity position coupled with our proposed
drilling joint venture will allow us the flexibility to navigate the
current commodity price volatility with a focus on the future. Finally,
we believe we possess a well-balanced hedge book through the end of the
fiscal year 2018, which will provide additional certainty of cash flows
as we look toward the future."

Commodity Derivatives

The Company engages in a number of different commodity trading program
strategies as a risk management tool to attempt to mitigate the
potential negative impact on cash flows caused by price fluctuations in
natural gas, NGL and oil prices. Below is a table that illustrates the
Company's hedging activities as of June 30, 2017:

Natural Gas Derivatives

  Volume      

Weighted Average

Description (MMBtu/d) Production Period Price ($/MMBtu)
Natural Gas Swaps:  
10,000 July 2017 – December 2017 $ 2.98
10,000 July 2017 – December 2017 $ 3.21
30,000 October 2017 – March 2018 $ 3.46
Natural Gas Three-way Collars:
Floor purchase price (put) 160,000 July 2017 – December 2017 $ 2.83
Ceiling sold price (call) 160,000 July 2017 – December 2017 $ 3.37
Floor sold price (put) 160,000 July 2017 – December 2017 $ 2.31
Floor purchase price (put) 30,000 July 2017 – March 2019 $ 3.00
Ceiling sold price (call) 30,000 July 2017 – March 2019 $ 3.40
Floor sold price (put) 20,000

July 2017 – March 2019

$ 2.40
Floor sold price (put) 10,000 July 2017 – March 2019 $ 2.20
Floor purchase price (put) 20,000 October 2017 – December 2018 $ 2.90
Ceiling sold price (call) 20,000 October 2017 – December 2018 $ 3.50
Floor sold price (put) 20,000 October 2017 – December 2018 $ 2.20
Floor purchase price (put) 60,000 January 2018 – March 2018 $ 2.90
Ceiling sold price (call) 60,000 January 2018 – March 2018 $ 3.75
Floor sold price (put) 60,000 January 2018 – March 2018 $ 2.40
Floor purchase price (put) 60,000 April 2018 – December 2018 $ 2.90
Ceiling sold price (call) 60,000 April 2018 – December 2018 $ 3.25
Floor sold price (put) 60,000 April 2018 – December 2018 $ 2.40
Floor purchase price (put) 60,000 January 2018 – December 2018 $ 2.80
Ceiling sold price (call) 60,000 January 2018 – December 2018 $ 3.35
Floor sold price (put) 60,000 January 2018 – December 2018 $ 2.33
Floor purchase price (put) 20,000 July 2017 – December 2018 $ 2.90
Ceiling sold price (call) 20,000 July 2017 – December 2018 $ 3.25
Floor sold price (put) 20,000 July 2017 – December 2018 $ 2.40
Natural Gas Call/Put Options:
Call sold 40,000 January 2018 – December 2018 $ 3.75
Call sold 10,000 January 2019 – December 2019 $ 4.75
Basis Swaps:
TCO - Columbia 20,000 July 2017 – December 2017 $ (0.19 )
Appalachia - Dominion 40,000 July 2017 – November 2017 $ (1.01 )
Appalachia - Dominion 40,000 July 2017 – November 2017 $ (1.04 )
 

Oil Derivatives

  Volume       Weighted Average
Description (Bbls/d) Production Period Price ($/Bbl)
Oil Three-way Collars:  
Floor purchase price (put) 2,000 July 2017 – September 2017 $ 46.00
Ceiling sold price (call) 2,000 July 2017 – September 2017 $ 59.50
Floor sold price (put) 2,000 July 2017 – September 2017 $ 38.00
Floor purchase price (put) 2,000 July 2017 – December 2017 $ 46.00
Ceiling sold price (call) 2,000 July 2017 – December 2017 $ 60.00

Floor sold price (put)

2,000 July 2017 – December 2017 $ 38.00
 

NGL Derivatives

  Volume       Weighted Average
Description (Gal/d) Production Period Price ($/Gal)
Propane Swaps:  
84,000 July 2017 – December 2017 $ 0.60
 

Subsequent to June 30, 2017, the Company entered into the following
derivative instruments:

       
Volume Production Weighted Average
Description (Bbls/d) Period Price ($/Bbl)
Oil Three-way Collars:  
Floor purchase price (put) 4,000 January 2018 – December 2018 $ 45.00
Ceiling sold price (call) 4,000 January 2018 – December 2018 $ 52.26
Floor sold price (put) 4,000 January 2018 – December 2018 $ 35.00
 

Guidance

The Company issued the following third quarter and full year 2017
guidance in the table below:

   
Q3 2017 FY 2017
Production MMcfe/d 350 - 355 315 - 320
% Gas 80% - 85% 77% - 81%
% NGL 10% - 12% 11% - 15%
% Oil 5% - 7% 7% - 9%
Gas Price Differential ($/Mcf)1,2 $(0.60) - $(0.70) $(0.25) - $(0.35)
Oil Differential ($/Bbl)1 $(6.50) - $(7.00) $(6.00) - $(7.00)
NGL Prices (% of WTI)1 30% - 35% 35% - 40%
Cash Production Costs ($/Mcfe)3 $1.20 - $1.25 $1.40 - $1.45
Cash G&A ($mm)4 $9.0 - $10.0 $35 - $37
CAPEX ($mm)5 ~$300
 

1.

 

Excludes impact of hedges.

2.

Excludes the cost of firm transportation.

3.

Includes lease operating, transportation, gathering and
compression, production and ad valorem taxes.

4.

Non-GAAP measure which excludes non-cash compensation, see
reconciliation to the most comparable GAAP measure at the end of
the financial statements included in this press release.

5.

Excludes potential acquisitions and payments of approximately
$17 million for land leased in 2016 which are expected to be paid
in 2017.

 

Conference Call

A conference call to review the Company's financial second quarter 2017
earnings is scheduled for Thursday, August 3, 2017, at 10:00 a.m.
(Eastern). To participate in the call, please dial 877-709-8150, or
201-689-8354 for international callers, and reference Eclipse Resources
Second Quarter Earnings Call. A replay of the call will be available
through October 4, 2017. To access the phone replay dial 877-660-6853 or
201-612-7415 for international callers. The conference ID is 13667027. A
live webcast of the call may be accessed through the "Investors" section
of the Company's website at www.eclipseresources.com.

   
ECLIPSE RESOURCES CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share and per share amounts)

(Unaudited)

 
June 30, December 31,
2017 2016
ASSETS
CURRENT ASSETS
Cash and cash equivalents $ 97,075 $ 201,229
Accounts receivable 40,438 44,423
Assets held for sale 404 468
Other current assets   4,426   4,295
Total current assets 142,343 250,415
 
PROPERTY AND EQUIPMENT AT COST
Oil and natural gas properties, successful efforts method:
Unproved properties 492,058 526,270
Proved oil and gas properties, net 567,724 414,482
Other property and equipment, net   6,271   6,748
Total property and equipment, net 1,066,053 947,500
 
OTHER NONCURRENT ASSETS
Other assets   3,861   729
TOTAL ASSETS $ 1,212,257 $ 1,198,644
 
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable $ 56,623 $ 44,049
Accrued capital expenditures 15,329 11,083
Accrued liabilities 20,174 55,044
Accrued interest payable 21,239 21,098
Liabilities held for sale   189   245
Total current liabilities 113,554 131,519
 
NONCURRENT LIABILITIES
Debt, net of unamortized discount and debt issuance costs 493,644 492,278
Asset retirement obligations 5,598 4,806
Other liabilities   2,156   13,434
Total liabilities 614,952 642,037
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS' EQUITY
Preferred stock, 50,000,000 authorized, no shares issued and
outstanding
Common stock, $0.01 par value, 1,000,000,000 authorized, 262,738,442

and 260,591,893 shares issued and outstanding, respectively

2,637 2,607
Additional paid in capital 1,963,090 1,958,731
Treasury stock, shares at cost; 991,247 and 72,704 shares,
respectively
(2,093 ) (61 )
Accumulated deficit   (1,366,329 )   (1,404,670 )
Total stockholders' equity   597,305   556,607
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY $ 1,212,257 $ 1,198,644
   
ECLIPSE RESOURCES CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)

 

For the Three Months Ended

For the Six Months Ended
June 30, June 30,
2017   2016 2017   2016
REVENUES
Natural gas, oil and natural gas liquids sales $ 86,194 $ 45,901 $ 185,625 $ 86,389
Brokered natural gas and marketing revenue   (3 )   1,165   2,428   10,283
Total revenues 86,191 47,066 188,053 96,672
 
OPERATING EXPENSES
Lease operating 4,568 2,248 6,911 4,925
Transportation, gathering and compression 28,969 28,254 61,846 51,391
Production and ad valorem taxes 2,033 2,203 3,964 4,766
Brokered natural gas and marketing expense 6 2,160 2,466 11,562
Depreciation, depletion and amortization 25,152 20,949 51,341 36,062
Exploration 8,997 17,444 20,577 33,100
General and administrative 10,730 10,402 20,862 21,676
Rig termination and standby 1,292 3,955
Impairment of proved oil and gas properties 17,665
Accretion of asset retirement obligations 128 89 252 175
(Gain) loss on sale of assets   6   (1,024 )   1   (1,046 )
Total operating expenses   80,589   84,017   168,220   184,231
OPERATING INCOME (LOSS) 5,602 (36,951 ) 19,833 (87,559 )
OTHER INCOME (EXPENSE)
Gain (loss) on derivative instruments 18,177 (29,596 ) 43,274 (19,046 )
Interest expense, net (12,285 ) (12,439 ) (24,747 ) (25,900 )
Gain (loss) on early extinguishment of debt 5,825 14,489
Other income (expense)     (2 )   (19 )   (141 )
Total other expense, net   5,892   (36,212 )   18,508   (30,598 )
INCOME (LOSS) BEFORE INCOME TAXES 11,494 (73,163 ) 38,341 (118,157 )
INCOME TAX BENEFIT (EXPENSE)         (540 )
NET INCOME (LOSS) $ 11,494 $ (73,163 ) $ 38,341 $ (118,697 )
 
NET INCOME (LOSS) PER COMMON SHARE
Basic $ 0.04 $ (0.33 ) $ 0.15 $ (0.53 )
Diluted $ 0.04 $ (0.33 ) $ 0.15 $ (0.53 )
 
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic 262,423 223,013 261,768 222,898
Diluted 264,420 223,013 264,321 222,898
 

Adjusted Revenue

Adjusted revenue is a non-GAAP financial measure. The Company defines
Adjusted revenue as follows: total revenues plus net cash receipts or
payments on settled derivative instruments less brokered natural gas and
marketing revenue. The Company believes Adjusted revenue provides
investors with helpful information with respect to the performance of
the Company's operations and management uses Adjusted revenue to
evaluate its ongoing operations and for internal planning and
forecasting purposes. See the table below, which reconciles Adjusted
revenue and total revenues.

   

For the Three Months Ended

For the Six Months Ended

June 30, June 30,
$ thousands 2017   2016 2017   2016
Total revenues $ 86,191 $ 47,066 $ 188,053 $ 96,672
Net cash receipts (payments) on derivative

instruments

(2,644 ) 12,880 (6,633 ) 31,258
Brokered natural gas and marketing revenue   3   (1,165 )   (2,428 )   (10,283 )
Adjusted revenue $ 83,550 $ 58,781 $ 178,992 $ 117,647
 

Adjusted Net Income (Loss)

Adjusted net income (loss) represents income (loss) before income taxes
adjusted for certain non-cash items as set forth in the table below. We
believe Adjusted net income (loss) is used by many investors and
published research in making investment decisions and 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 net income (loss) as determined by GAAP. See the table below
for a reconciliation of Adjusted net income (loss) and net income (loss).

   
Three Months Ended Six Months Ended June
June 30, 30,
$ thousands 2017   2016 2017   2016
Income (loss) before income taxes, as reported $ 11,494 $ (73,163 ) $ 38,341 $ (118,157 )
(Gain) loss on derivative instruments (18,177 ) 29,596 (43,274 ) 19,046
Net cash receipts (payments) on derivative instruments (2,644 ) 12,880 (6,633 ) 31,258
Rig termination and standby 1,292 3,955
Impairment of proved oil and gas properties 17,665
Dry hole and other 79

511

942 548
Stock-based compensation 2,348 2,226 4,429 3,701
Impairment of unproved properties 4,125 9,360 8,250 18,720
Other (income) expense 2 19 141
Gain on early extinguishment of debt (5,825 ) (14,489 )
(Gain) loss on sale of assets   6   (1,024 )   1   (1,046 )
Loss before income taxes, as adjusted (2,769 ) (24,145 ) 2,075 (38,658 )
Income tax benefit (expense)         (540 )
Adjusted net income (loss) $ (2,769 ) $ (24,145 ) $ 2,075 $ (39,198 )
 
Net income (loss) per Common Share
Basic $ 0.04 $ (0.33 ) $ 0.15 $ (0.53 )
Diluted $ 0.04 $ (0.33 ) $ 0.15 $ (0.53 )
 
Adjusted net income (loss) per Common Share
Basic $ (0.01 ) $ (0.11 ) $ 0.01 $ (0.18 )
Diluted $ (0.01 ) $ (0.11 ) $ 0.01 $ (0.18 )
 
Weighted Average Common Shares Outstanding
Basic 262,423 223,013 261,768 222,898
Diluted 264,420 223,013 264,321 222,898
 

Adjusted EBITDAX

Adjusted EBITDAX is a supplemental non-GAAP measure that is used by the
Company to evaluate its financial results. The Company defines Adjusted
EBITDAX as net income or loss before interest expense; income taxes;
impairments; depreciation, depletion and amortization ("DD&A"); gain
(loss) on derivative instruments, net cash receipts (payments on settled
derivative instruments, and premiums (paid) received on options that
settled during the period); non-cash compensation expense; gain or loss
from sale of interest in gas properties; exploration expenses; and other
unusual or infrequent items set forth in the table below. Adjusted
EBITDAX is not a measure of net income or loss as determined by GAAP.
See the table below for a reconciliation of Adjusted EBITDAX to net
income or net loss.

   
Three Months Ended Six Months Ended
June 30, June 30,
$ thousands 2017   2016   2017   2016
Net income (loss) $ 11,494 $ (73,163 ) $ 38,341 $ (118,697 )
Depreciation, depletion and amortization 25,152 20,949 51,341 36,062
Exploration expense 8,997 17,444 20,577 33,100
Rig termination and standby 1,292 3,955
Impairment of proved oil and gas properties 17,665
Stock-based compensation 2,348 2,226 4,429 3,701
Accretion of asset retirement obligations 128 89 252 175
(Gain) loss on derivative instruments (18,177 ) 29,596 (43,274 ) 19,046
Net cash receipts (payments) on settled derivatives (2,644 ) 12,880 (6,633 ) 31,258
Interest expense, net 12,285 12,439 24,747 25,900
(Gain) loss on sale of assets 6 (1,024 ) 1 (1,046 )
(Gain) loss on early extinguishment of debt (5,825 ) (14,489 )
Other (income) expense 2 19 141
Income tax (benefit) expense         540
Adjusted EBITDAX $ 39,589 $ 16,905 $ 89,800 $ 37,311
 

Cash General and Administrative Expenses

Cash General and Administrative Expenses is a non-GAAP financial measure
used by the Company in the Guidance Table to provide a measure of
administrative expenses used by many investors and published research in
making investment decisions and evaluating operational trends of the
Company. See the table below for a reconciliation of Cash General and
Administrative Expenses and General and Administrative Expenses.

   
Guidance
For the Three

For the Three

 

 

Months Ended

Months Ending

For the Year Ending

$ thousands June 30, 2017

September 30, 2017

December 31, 2017

General and administrative expenses, estimated to be

reported

$ 10,730 $ 11,000-$13,000 $ 44,500-$47,500
Stock-based compensation expense   (2,348 )   (2,000-3,000 )   (9,500-10,500 )

Cash general and administrative expenses

$ 8,382 $ 9,000-$10,000   $ 35,000-$37,000  
 

About Eclipse Resources

Eclipse Resources is an independent exploration and production company
engaged in the acquisition and development of oil and natural gas
properties in the Appalachian Basin, including the Utica and Marcellus
Shales. For more information, please visit the Company's website at www.eclipseresources.com.

Forward-Looking Statements

This press release contains "forward-looking statements" within the
meaning of Section 27A of the Securities Act of 1933, as amended (the
"Securities Act") and Section 21E of the Securities Exchange Act of
1934, as amended (the "Exchange Act"). All statements, other than
statements of historical fact included in this press release, regarding
Eclipse Resources' strategy, future operations, financial position,
estimated revenues and income/losses, projected costs and capital
expenditures, prospects, plans and objectives of management are
forward-looking statements. When used in this press release, the words
"plan," "endeavor," "will," "would," "could," "believe," "anticipate,"
"intend," "estimate," "expect," "project" and similar expressions are
intended to identify forward-looking statements, although not all
forward-looking statements contain such identifying words. These
forward-looking statements are based on Eclipse Resources' current
expectations and assumptions about future events and are based on
currently available information as to the outcome and timing of future
events. When considering forward-looking statements, you should keep in
mind the risk factors and other cautionary statements described under
the heading "Risk Factors" in Eclipse Resources' Annual Report on Form
10-K filed with the Securities Exchange Commission on March 3, 2017 (the
"2016 Annual Report"), and in "Item 1A. Risk Factors" of Eclipse
Resources' Quarterly Reports on Form 10-Q.

Forward-looking statements may include statements about Eclipse
Resources' business strategy; reserves; our proposed drilling joint
venture with Sequel; general economic conditions; financial strategy,
liquidity and capital required for developing its properties and timing
related thereto; realized natural gas, NGLs and oil prices; timing and
amount of future production of natural gas, NGLs and oil; its hedging
strategy and results; future drilling plans; competition and government
regulations, including those related to hydraulic fracturing; the
anticipated benefits under its commercial agreements; pending legal
matters relating to its leases; marketing of natural gas, NGLs and oil;
leasehold and business acquisitions; the costs, terms and availability
of gathering, processing, fractionation and other midstream services;
general economic conditions; credit markets; uncertainty regarding its
future operating results, including initial production rates and liquid
yields in its type curve areas; and plans, objectives, expectations and
intentions contained in this press release that are not historical.

Eclipse Resources 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 its 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; legal and environmental risks, drilling and other operating risks,
regulatory changes, commodity price volatility and the recent
significant decline of the price of natural gas, NGLs, and oil,
inflation, lack of availability of drilling, production and processing
equipment and services, our inability to successfully negotiate or enter
into definitive agreements and satisfy other conditions precedent for
our proposed joint venture drilling transaction with Sequel,
and
to effectively implement that transactio
n, counterparty credit
risk, the uncertainty inherent in estimating natural gas, NGLs 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 "Risk Factors" in the 2016 Annual
Report and in "Item 1A. Risk Factors" of Eclipse Resources' Quarterly
Reports on Form 10-Q.

All forward-looking statements, expressed or implied, included in
this press release are expressly qualified in their entirety by this
cautionary statement. This cautionary statement should also be
considered in connection with any subsequent written or oral
forward-looking statements that Eclipse Resources or persons acting on
the Company's behalf may issue.

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