Market Overview

WildHorse Resource Development Corporation Announces Third Quarter Results

Share:

WildHorse Resource Development Corporation (NYSE:WRD) announced today
its operating and financial results for the three months ended September
30, 2018. Highlights from the quarter include:

  • Entered into an Agreement and Plan of Merger ("Merger Agreement") on
    October 29, 2018 with Chesapeake Energy Corporation ("Chesapeake") and
    Coleburn Inc. ("Merger Sub"), a wholly owned subsidiary of Chesapeake,
    pursuant to which Chesapeake will acquire WRD in exchange for shares
    of Chesapeake common stock or a combination of cash and common stock
    at the election of each WRD stockholder
  • Increased average daily production by 34% to 49.0 Mboe/d for the third
    quarter 2018 compared to 36.6 Mboe/d for the third quarter 2017
  • Brought online 27 gross (25.8 net) Eagle Ford wells and 4 gross (3.3
    net) Austin Chalk wells in the third quarter of 2018
  • Crude oil realizations in the third quarter of 2018 were 104% of WTI
    as a result of low differentials and favorable Gulf Coast pricing
  • The Windel Goodson A 1H/Stern 144 Christian EF Unit #1H and #2H, three
    Eagle Ford wells in Burleson County, achieved an average peak IP-30(1)
    of 833 Boe/d (91% oil) on an average 7,421' lateral
  • The Madeline 1H/Baggett 1H, a 2-well Austin Chalk pad in Washington
    County, achieved an average peak IP-30(1) of 2,444 Boe/d
    (15% oil, 31% NGLs, and 54% natural gas) or 14.7 MMcfe/d on an average
    5,581' lateral
  • The Thorpe #1H/Draeger #1H, a 2-well Austin Chalk pad in Washington
    County, achieved an average peak 24-hr IP rate(1) of 2,584
    Boe/d (1% oil, 36% NGLs, and 63% natural gas) or 15.5 MMcfe/d on an
    average 5,752' lateral
  • Achieved the fastest drilled WRD Austin Chalk well to date at 17.9
    days from spud to rig release and reduced the target Austin Chalk
    drilling time in Washington County from 30 to 24 days spud to rig
    release
  • Built sand inventory of 200,000 tons of mined stockpiles and 70,000
    tons of processed material from WRD's sand mine

Jay Graham, Chief Executive Officer and Chairman of the Board of
Directors of WildHorse Resource Development said, "We are extremely
proud of the company we built and brought public less than two years
ago. The combination of WildHorse and Chesapeake creates an impressive
oil growth platform which provides both immediate value and potential
for significant long-term upside to our shareholders. As a highly
regarded operator, Chesapeake brings the technical expertise and
operational efficiencies needed to maximize the value of this premier
asset."

Proposed Merger with Chesapeake Energy Corporation

On October 29, 2018, WRD, Chesapeake, and Merger Sub entered into a
Merger Agreement pursuant to which Chesapeake will acquire WRD in
exchange for shares of Chesapeake common stock or combination of cash
and common stock. At the election of each WildHorse common stockholder,
the consideration will consist of either 5.989 shares of Chesapeake
common stock or a combination of 5.336 shares of Chesapeake common stock
and $3 in cash, in exchange for each issued and outstanding share of
WildHorse common stock. Following the approval by WRD stockholders and
Chesapeake shareholders and certain closing conditions, the merger is
expected to close during the first half 2019.

In light of the pending merger with Chesapeake, WRD has discontinued
providing guidance and long-term outlook information regarding its
results of operations. In addition, investors are cautioned not to rely
on historical forward-looking statements regarding guidance and
long-term outlook information, which forward-looking statements spoke
only as of the date provided and were subject to the specific risks and
uncertainties that accompanied such forward-looking statements.
Chesapeake will file with the SEC a registration statement on Form S-4
that will include a joint proxy statement of Chesapeake and WRD and a
prospectus of Chesapeake, as well as other relevant documents concerning
the pending merger.

Third Quarter 2018 Results

Net production was 49.0 Mboe/d for the third quarter 2018 compared to
36.6 Mboe/d for the third quarter 2017. Third quarter 2018 net
production consisted of approximately 35.5 Mbbls/d oil, 6.2 Mboe/d NGLs,
and 43.3 MMcf/d natural gas.

WRD reported Net Income of $11.5 million for the third quarter 2018 in
comparison to a Net Loss of $10.8 million for the third quarter 2017.
Net Income available to common stockholders was $3.5 million or $0.04
per share for the third quarter 2018 in comparison to a Net Loss
available to common stockholders of $17.3 million or $0.17 per share for
the third quarter 2017.

Adjusted Net Income available to common stockholders(2) for
the third quarter 2018 was $37.8 million or $0.38 per share in
comparison to Adjusted Net Income available to common stockholders(2)
of $11.6 million or $0.12 per share for the third quarter 2017. In the
third quarter 2018, Reported and Adjusted Net Income available to common
shareholders was impacted by the recognition of $11.4 million of
Geological and Geophysical ("G&G") exploration expense primarily related
to our recent five-well test pad.

WRD reported Adjusted EBITDAX(2) for the third quarter 2018
of $185.8 million compared to Adjusted EBITDAX(2) for the
third quarter 2017 of $98.4 million.

Total revenues and other income for the third quarter 2018, excluding
the impact of realized hedges, were $259.5 million compared to $122.5
million for the third quarter 2017. Total revenues were higher primarily
as a result of increased production and higher commodity prices. Crude
oil price realizations were 104% of WTI as a result of a low
transportation differential and favorable Gulf Coast pricing. NGL price
realizations were 35% of WTI and greater than the second quarter 2018
primarily as a result of stronger ethane pricing. Natural gas price
realizations were 80% of Henry Hub and greater than the second quarter
2018 primarily as a result of stronger Houston Ship Channel pricing in
the third quarter 2018.

Average realized prices for the quarters ending September 30, 2018 and
2017, before the effect of commodity derivatives, are presented below:

            Percent
Q3'18 Q3'17 Change
Oil (per Bbl) $ 72.23 $ 47.89 51 %
Natural Gas (per Mcf) $ 2.33 $ 2.90 -20 %
NGL (per BbL) $ 24.29 $ 16.65 46 %
Total (per Boe) $ 57.56 $ 36.30 59 %

Average realized prices for the quarters ending September 30, 2018 and
2017, after the effect of commodity derivatives, are presented below:

            Percent
Q3'18 Q3'17 Change
Oil (per Bbl) $ 62.45 $ 49.58 26 %
Natural Gas (per Mcf) $ 2.26 $ 2.99 -24 %
NGL (per BbL) $ 24.29 $ 16.65 46 %
Total (per Boe) $ 50.40 $ 37.49 34 %

Lease operating expense ("LOE") for the third quarter 2018 was $14.2
million, or $3.16 per Boe, compared to $12.4 million, or $3.70 per Boe,
for the third quarter 2017. The decline in LOE per Boe was the result of
optimized chemicals usage and more favorable procurement and labor
contracts.

Gathering, processing and transportation expense ("GP&T") for the third
quarter 2018 was $3.2 million, or $0.72 per Boe, compared to $0.5
million, or $0.11 per Boe, in the second quarter 2018. GP&T expense
increased over the last quarter as a result of recognizing a portion of
oil trucking costs in GP&T rather than in realized revenues primarily
due to a change in our marketing contracts. However, GP&T expense over
the previous year was significantly lower on a Boe basis due to the
implementation of the new FASB revenue recognition standard ASC 606,
effective as of January 1, 2018, and the sale of WRD's North Louisiana
assets. In addition, natural gas and NGL revenue realizations were also
impacted under the new standard. For additional information, please see
the appendix of this press release and the Management's Discussion &
Analysis section of WRD's third quarter 2018 Form 10-Q for a
reconciliation of GP&T and pricing realizations to the previous
accounting convention.

Taxes other than income were $14.2 million for the third quarter 2018,
or $3.15 per Boe, compared to $6.0 million, or $1.80 per Boe, for the
third quarter 2017. Taxes other than income in the third quarter 2018
increased primarily due to higher price realizations and increased crude
oil in the commodity mix.

General and administrative ("G&A") expense for the third quarter 2018
was $16.0 million, or $3.56 per Boe, compared to $11.0 million, or $3.28
per Boe, for the third quarter 2017. G&A expense increased over last
year largely as a result of additional employees hired and stock-based
compensation expense. During the third quarter 2018, G&A expense
included $4.9 million, or $1.09 per Boe, of stock-based compensation
expense and $0.4 million, or $0.09 per Boe, of acquisition related
costs. Excluding acquisition related costs, cash G&A expense(2),
which does not include stock-based compensation, was $10.7 million or
$2.37 per Boe for the third quarter 2018.

Exploration expense was $13.8 million for the third quarter 2018
compared to $4.7 million for the third quarter 2017. Exploration
expenses were higher in the third quarter 2018 as a result of greater
G&G exploration expense primarily related to WRD's recent five-well test
pad.

Net interest expense during the third quarter 2018 was $15.7 million,
including amortization of deferred financing fees of approximately $0.8
million. This compares to net interest expense during the third quarter
2017 of $8.7 million, including amortization of deferred financing fees
of approximately $0.7 million. The increase in net interest expense is
primarily the result of higher levels of indebtedness due to the
issuance of additional senior notes in September 2017 and April 2018.

Drilling and completion ("D&C") capital expenditures totaled $207.4
million in the third quarter 2018 and $657.3 million for the first nine
months of 2018. In the third quarter 2018, WRD released its fifth
drilling rig and third completion crew. As a result, D&C capital
expenditures are expected to be lower in the fourth quarter 2018. Sand
mine expenditures totaled $19.4 million in the third quarter 2018 and
$44.5 million for the first nine months of 2018. Sand mine expenditures
in 2018 are expected to be at the mid-point of the annual guidance range
of $65 to $75 million.

   

(1)

The initial production rates represent the peak average of the
initial production rates for the applicable time period of
production.

(2)

Adjusted EBITDAX, Adjusted Net Income (Loss) available to common
stockholders, Cash G&A, and net debt are financial measures not
calculated in accordance with accounting principles generally
accepted in the United States of America ("GAAP"). Please see the
reconciliation to the most comparable measures calculated in
accordance with GAAP in the "Use of Non-GAAP Financial Measures"
section of this press release.
 

Operational Update

WRD reported third quarter 2018 average daily production of 49.0 Mboe/d
consisting of 73% oil, 15% natural gas, and 12% NGLs. WRD brought online
a total of 31 gross (29.1 net) wells including 27 gross (25.8 net) Eagle
Ford wells, 4 gross (3.3 net) Austin Chalk wells, and 4 refracs in the
third quarter 2018.

In the Eagle Ford, the Windel Goodson A 1H/Stern 144 Christian EF Unit
#1H/ Stern 144 Christian EF #2H, three Eagle Ford wells in Burleson
County, achieved an average peak IP-30(1) of 833 Boe/d (91%
oil) on an average 7,421' lateral.

In the Austin Chalk, WRD brought online 4 gross wells. The Madeline
1H/Baggett 1H, a 2-well Austin Chalk pad in Washington County, achieved
an average peak IP-30(1) of 2,444 Boe/d (15% oil, 31% NGLs,
and 54% natural gas) on an average 5,581' lateral.

Another Austin Chalk two-well pad in Washington County, the Thorpe
#1H/Draeger #1H, was brought online in late September and has so far
achieved an average peak 24-hr IP rate(1) of 2,584 Boe/d (1%
oil, 36% NGLS, and 63% natural gas) on an average 5,752' lateral. The
Thorpe #1H was the fastest WRD drilled Austin Chalk well to date at 17.9
days from spud to rig release. Due to the continued drilling
outperformance in the Austin Chalk, WRD is lowering its target Austin
Chalk drill time in Washington County from 30 days to 24 days spud to
rig release. WRD expects to have one additional Austin Chalk well in
Washington County in the fourth quarter bringing the total to 9 Austin
Chalk wells for the year.

Financial Update

Total net debt(2) outstanding as of September 30, 2018 was
approximately $1.1 billion, including $399.0 million of debt outstanding
under WRD's revolving credit facility, $700 million of Senior Notes due
2025, and $1.7 million in cash and cash equivalents. As of September 30,
2018 and pro-forma for the $250 million borrowing base increase on
October 15, 2018, WRD's liquidity was $902.7 million consisting of $1.7
million of cash and cash equivalents and $901.0 million of availability
under its revolving credit facility. WRD expects the available
borrowings under its revolving credit facility to provide sufficient
liquidity to finance anticipated working capital and capital expenditure
requirements. WRD's net debt(2) to annualized third quarter
2018 Adjusted EBITDAX(2) ratio was 1.5x.

Hedging Update

WRD utilizes its hedging program to mitigate financial risks and the
effects of commodity price volatility. Total hedged production in the
third quarter of 2018 was approximately 2.6 MMboe, or 59% of third
quarter production of 4.5 MMboe. As of November 7, 2018, WRD had hedged
approximately 72% of its fourth quarter 2018 production on a barrel of
oil equivalent basis (using the mid-point of WRD's annual guidance
range). With a combination of puts and unhedged production, WRD
maintains upside on approximately 52% of its fourth quarter 2018 oil
production.

The following table reflects WRD's hedged volumes and corresponding
weighted-average price, as of November 7, 2018.

       
Q4 '18   2019   2020
 
Crude Oil Hedge Contracts:
Total crude oil volumes hedged (Bbl) 2,388,326 8,402,126 4,511,681
Volumes hedged (Bbl/d) 25,960 23,020 12,327
Total weighted-average price $ 51.18 $ 54.32 $ 53.49
Expected crude production hedged (3) 82 % - -
 
Natural Gas Hedge Contracts:
Total natural gas volumes hedged (MMbtu) 2,184,376 6,425,146 4,846,020
Volumes hedged (MMbtu/d) 23,743 17,603 13,240
Total weighted-average price $ 2.79 $ 2.79 $ 2.76
 
Total Hedge Contracts:
Total hedged production (boe) 2,752,389 9,472,984 5,319,351
Volumes hedged (Boe/d) 29,917 25,953 14,534
Total weighted-average price ($/boe) $ 44.78 $ 48.49 $ 45.79
Expected total production hedged (3) 72 % - -
 
LLS Basis Swaps
Total crude oil volumes hedged (Bbl) 1,711,789 - -
Volumes hedged (Bbl/d) 18,606 - -
Total weighted-average price - WTI to LLS $ 3.02 - -
Expected oil basis production hedged (3) 59 % - -
 
 

(3)

  Using the mid-point of WRD's 2018 guidance ranges.
 

Additional Information

WRD will not host an earnings conference call. WRD's financial
statements and related footnotes will be available in its Quarterly
Report on Form 10-Q for the quarter ended September 30, 2018, which will
be filed with the U.S. Securities and Exchange Commission ("SEC") on or
before November 9, 2018.

About WildHorse Resource Development Corporation

WildHorse Resource Development Corporation is an independent oil and
natural gas company focused on the acquisition, exploration, development
and production of oil, natural gas and NGL properties primarily in the
Eagle Ford Shale and Austin Chalk in East Texas. For more information,
please visit our website at www.wildhorserd.com.

Important Information for Investors and Shareholders

This communication may contain certain forward-looking statements,
including certain plans, expectations, goals, projections, and
statements about the benefits of the proposed transaction, WRD's and
Chesapeake's plans, objectives, expectations and intentions, the
expected timing of completion of the transaction, business strategy and
measures to implement strategy, competitive strengths, goals, expansion
and growth of WRD's business and operations, plans, successful
consummation and integration of acquisitions and other transactions,
market conditions, references to future success, references to
intentions as to future matters and other statements that are not
historical facts. Such statements are subject to numerous assumptions,
risks, and uncertainties. Statements that do not describe historical or
current facts, including statements about beliefs and expectations, are
forward-looking statements. Forward-looking statements may be identified
by words such as expect, anticipate, believe, intend, estimate, plan,
target, goal, or similar expressions, or future or conditional verbs
such as will, may, might, should, would, could, or similar variations.
The forward-looking statements are intended to be subject to the safe
harbor provided by Section 27A of the Securities Act of 1933, Section
21E of the Securities Exchange Act of 1934, and the Private Securities
Litigation Reform Act of 1995.

While there is no assurance that any list of risks and uncertainties or
risk factors is complete, below are certain factors which could cause
actual results to differ materially from those contained or implied in
the forward-looking statements: 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; the
possibility that the proposed transaction does not close when expected
or at all because required regulatory, shareholder or other approvals
are not received or other conditions to the closing are not satisfied on
a timely basis or at all; the risk that regulatory approvals required
for the proposed merger are not obtained or are obtained subject to
conditions that are not anticipated; potential adverse reactions or
changes to business or employee relationships, including those resulting
from the announcement or completion of the transaction; uncertainties as
to the timing of the transaction; competitive responses to the
transaction; the possibility that the anticipated benefits of the
transaction are not realized when expected or at all, including as a
result of the impact of, or problems arising from, the integration of
the two companies; the possibility that the transaction may be more
expensive to complete than anticipated, including as a result of
unexpected factors or events; diversion of management's attention from
ongoing business operations and opportunities; the ability of Chesapeake
to complete the acquisition and integration of WRD successfully;
litigation relating to the transaction; and other factors that may
affect future results of WRD and Chesapeake.

Additional factors that could cause results to differ materially from
those described above can be found in WRD's Annual Report on Form 10-K
for the year ended December 31, 2017 and in its subsequent Quarterly
Reports on Form 10-Q for the quarters ended March 31, 2018 and June 30,
2018, each of which is on file with the SEC and available in the
"Investor Relations" section of WRD's website,
https://www.wildhorserd.com/, under the subsection "SEC Filings" and in
other documents WRD files with the SEC, and in Chesapeake's Annual
Report on Form 10-K for the year ended December 31, 2017 and in its
subsequent Quarterly Reports on Form 10-Q for the quarters ended March
31, 2018, June 30, 2018, and September 30, 2018 each of which is on file
with the SEC and available in the "Investors" section of Chesapeake's
website, https://www.chk.com/, under the heading "SEC Filings" and in
other documents Chesapeake files with the SEC.

All forward-looking statements speak only as of the date they are made
and are based on information available at that time. Neither WRD nor
Chesapeake assumes any obligation to update forward-looking statements
to reflect circumstances or events that occur after the date the
forward-looking statements were made or to reflect the occurrence of
unanticipated events except as required by federal securities laws. As
forward-looking statements involve significant risks and uncertainties,
caution should be exercised against placing undue reliance on such
statements.

Important Additional Information

A portion of this communication relates to a proposed business
combination transaction (the "Transaction") between WildHorse Resource
Development Corporation ("WRD") and Chesapeake Energy Corporation
("Chesapeake"). This communication is for informational purposes only
and does not constitute an offer to sell or the solicitation of an offer
to buy any securities or a solicitation of any vote or approval, in any
jurisdiction, pursuant to the Transaction or otherwise, nor shall there
be any sale, issuance, exchange or transfer of the securities referred
to in this document in any jurisdiction in contravention of applicable
law.

In connection with the Transaction, Chesapeake will file with the SEC a
registration statement on Form S-4 that will include a joint proxy
statement of Chesapeake and WRD and a prospectus of Chesapeake, as well
as other relevant documents concerning the Transaction. The Transaction
involving WRD and Chesapeake will be submitted to WRD's stockholders and
Chesapeake's shareholders for their consideration. STOCKHOLDERS OF WRD
AND SHAREHOLDERS OF CHESAPEAKE ARE URGED TO READ THE REGISTRATION
STATEMENT AND THE JOINT PROXY STATEMENT/PROSPECTUS REGARDING THE
TRANSACTION WHEN IT BECOMES AVAILABLE AND ANY OTHER RELEVANT DOCUMENTS
FILED WITH THE SEC, AS WELL AS ANY AMENDMENTS OR SUPPLEMENTS TO THOSE
DOCUMENTS, BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION. Investors
will be able to obtain a free copy of the registration statement and the
joint proxy statement/prospectus, as well as other filings containing
information about WRD and Chesapeake, without charge, at the SEC's
website (http://www.sec.gov). Copies of the documents filed with the SEC
can also be obtained, without charge, by directing a request to Investor
Relations, WRD, P.O. Box 79588, Houston, Texas 77279, Tel. No. (713)
255-9327 or to Investor Relations, Chesapeake, 6100 North Western
Avenue, Oklahoma City, Oklahoma, 73118, Tel. No. (405) 848-8000.

Participants in the Solicitation

WRD, Chesapeake and certain of their respective directors, executive
officers and employees may be deemed to be participants in the
solicitation of proxies in respect of the Transaction. Information
regarding WRD's directors and executive officers is available in its
definitive proxy statement, which was filed with the SEC on April 2,
2018, and certain of its Current Reports on Form 8-K. Information
regarding Chesapeake's directors and executive officers is available in
its definitive proxy statement, which was filed with the SEC on April 6,
2018, and certain of its Current Reports on Form 8-K. Other information
regarding the participants in the proxy solicitation and a description
of their direct and indirect interests, by security holdings or
otherwise, will be contained in the joint proxy statement/prospectus and
other relevant materials filed with the SEC. Free copies of this
document may be obtained as described in the preceding paragraph.

Additional Disclosures

Initial production rates are subject to decline over time and should not
be regarded as reflective of sustained production levels.

Some of the above results are preliminary. Such preliminary results are
based on the most current information available to management. As a
result, WRD's final results may vary from these preliminary estimates.
Such variances may be material; accordingly, you should not place undue
reliance on these preliminary estimates.

Cash General and Administrative Expenses per Boe

Our presentation of cash G&A expenses is a non-GAAP measure. We define
cash G&A as total G&A determined in accordance with GAAP less non-cash
equity compensation expenses, and we may express it on a per Boe basis.
We report and provide guidance on cash G&A because we believe this
measure is commonly used by management, analysts and investors as an
indicator of cost management and operating efficiency on a comparable
basis from period to period. In addition, management believes cash G&A
is used by analysts and others in valuation, comparison and investment
recommendations of companies in the oil and natural gas industry to
allow for analysis of G&A spend without regard to stock-based
compensation programs which can vary substantially from company to
company. Cash G&A should not be considered as an alternative to, or more
meaningful than, total G&A as determined in accordance with GAAP and may
not be comparable to other similarly titled measures of other companies.

Use of Non-GAAP Financial Measures

This press release and accompanying schedules include the non-GAAP
financial measures of Adjusted EBITDAX, Adjusted Net Income (Loss)
available to common stockholders, Cash G&A, and Net Debt. The
accompanying appendix and schedules provide a reconciliation of these
non-GAAP financial measures to their most directly comparable financial
measure calculated and presented in accordance with GAAP. WRD's non-GAAP
financial measures should not be considered as alternatives to GAAP
measures such as Net Income, operating income, net cash flows provided
by operating activities or any other measure of financial performance
calculated and presented in accordance with GAAP. WRD's non-GAAP
financial measures may not be comparable to similarly-titled measures of
other companies because they may not calculate such measures in the same
manner as WRD does.

   

WildHorse Resource Development Corporation
Statements
of Condensed Consolidated Operations

 
For the Three Months
Ended September 30,
(Amounts in $000s except per share data) 2018     2017

Revenues and other income:

Oil sales $ 236,040 $ 100,391
Natural gas sales 9,298 14,906
NGL sales 13,883 6,881
Other income   269     308  
Total operating revenues and other income   259,490     122,486  
 

Operating Expenses:

Lease operating expenses 14,221 12,435
Gathering, processing and transportation 3,225 3,761
Taxes other than income 14,193 6,047
Depreciation, depletion and amortization 74,842 51,843
General and administrative expenses 16,033 11,043
Exploration expense 13,814 4,749
(Gain) loss on sale of properties 217 -
Other operating (income) expense   169     9  
Total expenses   136,714     89,887  
 
Income (loss) from operations 122,776 32,599
 

Other Income (Expense):

Interest expense (15,718 ) (8,749 )
Gain (loss) on derivative instruments (76,358 ) (40,288 )
Other income (expense)   (122 )   (12 )
Total other income (expense)   (92,198 )   (49,049 )
 
Income (loss) before income taxes 30,578 (16,450 )
Income tax benefit (expense)   (19,055 )   5,646  
Net Income (loss)   11,523     (10,804 )
Preferred stock dividends 6,756 6,450
Undistributed earnings allocated to participating securities   1,233     -  
Net income (loss) available to common stockholders $ 3,534   $ (17,254 )
 
Earnings per share
Basic $ 0.04 (0.17 )
Diluted $ 0.04 (0.17 )
 
Weighted average shares outstanding
Basic 99,639 99,142
Diluted 99,639 99,142
   

WildHorse Resource Development Corporation
Statements
of Condensed Consolidated Cash Flows

 
For the Three Months
Ended September 30,
(Amounts in $000s) 2018   2017
 
Cash flows from operating activities:
Net Income (Loss) $ 11,523 $ (10,804 )
Adjustments to reconcile net income (loss) to cash flows
provided by operating activities
Depreciation, depletion and amortization 74,722 51,642
Accretion of asset retirement obligations 120 201
Impairments of unproved properties 2,360 3,247
Amortization of debt issuance costs 763 685
Accretion of senior note discount premium 3 92
(Gain) loss on derivative instruments 76,358 40,288
Cash settlements on derivative instruments (31,123 ) 5,802
Consideration paid to customers, net of amortization (478 ) -
Deferred income tax expense (benefit) 23,529 (6,630 )
Non-cash incentive unit compensation expense - -
Amortization of equity awards 4,997 2,414
(Gain) loss on sale of properties 217 -
Loss on equity investment 103 -
Changes in operating assets and liabilities   (7,227 )   (15,779 )
Net cash provided by operating activities   155,867     71,158  
 
Cash flows from investing activities:
Net cash used in investing activities   (316,181 )   (237,472 )
 
Cash flows from financing activities:
Net cash provided by financing activities   142,920     156,840  
 
Net change in cash, cash equivalents, and restricted cash $ (17,394 ) $ (9,474 )
Cash, cash equivalents and restricted cash, beginning of period   19,139     15,385  
Cash, cash equivalents and restricted cash, end of period $ 1,745   $ 5,911  
   

WildHorse Resource Development Corporation
Operating
Data

 
For the Three Months
Ended September 30,
2018     2017

Production volumes

Oil Sales (MBbls) 3,268 2,097
Natural Gas Sales (MMcf) 3,985 5,133
NGL Sales (MBbls)   572   413
Total (Mboe) 4,504 3,365
Total (Mboe/d) 49.0 36.6
 

Average unit costs per boe

Lease operating expense $ 3.16 $ 3.70
Gathering, processing and transportation $ 0.72 $ 1.12
Taxes other than income $ 3.15 $ 1.80
General and administrative expenses $ 3.56 $ 3.28
Cash General and administrative expenses $ 2.47 $ 2.56
Acquisition-related cost $ 0.09 $ 0.30
       

WildHorse Resource Development Corporation

Condensed Consolidated Balance Sheets

 
September 30,     December 31,
(Amounts in $000s) 2018 2017
 
ASSETS
Current Assets:
Cash and cash equivalents $ 1,745 $ 226
Accounts receivable, net 111,354 84,103
Derivative instruments - 2,336
Prepaid expenses and other current assets   5,734     3,290  
Total Current Assets 118,833 89,955
 
Property & equipment:
Oil and natural gas properties 3,271,422 2,999,728
Other property and equipment 79,120 53,003
Accumulated depreciation, depletion and impairment   (426,373 )   (368,245 )
Total property and equipment, net 2,924,169 2,684,486
 
Other noncurrent assets
Derivative instruments 574 86
Debt issuance costs 3,301 3,573
Other   17,575     -  
Total Assets $ 3,064,452   $ 2,778,100  
 
LIABILITIES AND EQUITY
Current Liabilities:
Accounts payable $ 66,423 $ 53,005
Accrued liabilities 169,665 199,952
Derivative instruments   131,539     58,074  
Total Current Liabilities 367,627 311,031
 
Noncurrent Liabilities:
Long-term debt 1,085,997 770,596
Asset retirement obligations 7,899 14,467
Deferred tax liabilities 44,141 71,470
Derivative instruments 81,736 18,676
Other noncurrent liabilities   762     1,085  
Total liabilities 1,588,162 1,187,325
 
Series A Perpetual Convertible Preferred Stock 447,726 445,483
 
Stockholders' equity:
Common stock 1,020 1,012
Additional paid-in capital 1,146,149 1,118,507
Accumulated earnings (deficit)   (118,605 )   25,773  
Total stockholders' equity 1,028,564 1,145,292
   
Total Liabilities & Equity $ 3,064,452   $ 2,778,100  
               

WildHorse Resource Development Corporation
Commodity
Hedge Positions

 

The following table reflects WRD's hedged volumes and
corresponding weighted-average price, as of November 7, 2018:

 
Q4 '18 2019 2020
Crude Oil Derivative Contracts:
Swap contracts:
Volume (Bbl) 1,398,947 6,652,369 4,511,681
Weighted-average fixed price $ 52.33 $ 54.45 $ 53.49
 
Deferred put options
Volume (Bbl) 989,379 1,749,757 -
Weighted-average floor price $ 49.55 $ 53.83 -
Weighted-average put premium ($3.69 ) ($5.43 ) -
 
LLS basis swaps
Volume (Bbl) 1,711,789 - -
Weighted-average fixed price - WTI to LLS $ 3.02 - -
 
 
Natural Gas Derivative Contracts:
Swap contracts:
Volume (MMBtu) 2,184,376 6,425,146 4,846,020
Weighted-average fixed price $ 2.79 $ 2.79 $ 2.76
 

Calculation of Adjusted EBITDAX:

We evaluate performance based on Adjusted EBITDAX. Adjusted EBITDAX is
defined as Net Income (loss), plus interest expense; debt extinguishment
costs; income tax expense; depreciation, depletion and amortization;
impairment of goodwill and long-lived properties; accretion of asset
retirement obligations; losses on commodity derivative contracts and
cash settlements received; losses on sale of properties; stock-based
compensation; incentive-based compensation expenses; exploration costs;
provision for environmental remediation; transaction related costs; IPO
related expenses; the North Louisiana settlement, and other non-routine
items, less interest income; income tax; unrealized gains/losses on
commodity derivative contracts and cash settlements paid; gains on sale
of assets and other non-routine items. The following table presents
WRD's information for the periods indicated:

   

Adjusted EBITDAX

 
For the Three Months
Ended September 30,
(Amounts in $000s) 2018       2017
Net Income (Loss) $ 11,523 $ (10,804 )

Add (Deduct):

Interest expense, net 15,718 8,749
Income tax (benefit) expense 19,055 (5,646 )
Depreciation, depletion and amortization 74,842 51,843
Exploration expense 13,814 4,749
(Gain) loss on derivative instruments 76,358 40,288
Cash settlements received / (paid) on commodity derivatives (31,123 ) 5,802
Stock-based compensation 4,997 2,414
Incentive unit compensation - -
Acquisition related costs 424 998
Gain on sale of North Louisiana disposal group 217 -
Debt Extinguishment costs   -     -  
Adjusted EBITDAX $ 185,825   $ 98,393  
 

Calculation of Adjusted Net Income (Loss) Available to Common
Stockholders:

Adjusted Net Income (Loss) available to common stockholders is a
supplemental non-GAAP financial measure that is used by external users
of WRD's financial statements. We define Adjusted Net Income (Loss)
available to common stockholders as Net Income (Loss) available to
common stockholders excluding the impact of certain items including
gains or losses on commodity derivative instruments not yet settled,
gains or losses on sales of properties, debt extinguishment costs,
stock-based compensation, incentive-unit compensation expense,
impairment-related expenses, the tax benefit related to the Tax Cuts and
Jobs Act, the North Louisiana settlement, and the tax effects related to
these adjustments. We believe Adjusted Net Income (Loss) available to
common stockholders is useful to investors because it provides readers
with a more meaningful measure of our profitability before recording
certain items for which the timing or amount cannot be reasonably
determined. However, this measure is provided in addition to, not as an
alternative for, and should be read in conjunction with, the information
contained in our financial statements prepared in accordance with GAAP.
The following table provides a reconciliation of Net Income (Loss)
available to common stockholders as determined in accordance with GAAP
to Adjusted Net Income (Loss) available to common stockholders for the
periods indicated:

   

Adjusted Net Income (Loss) available to common stockholders

 
For the Three Months
Ended September 30, 2018
(Amounts in $000s)     (Basic / Diluted EPS)
 
Net Income (Loss) available to common stockholders $ 3,534 $ 0.04
 
Add (Deduct)
(Gain) loss on derivative instruments 76,358 0.77
Cash settlements received / (paid) on commodity derivatives (31,123 ) (0.31 )
Stock-based compensation 4,997 0.05
Impairment of oil and gas properties 2,360 0.02
Incentive unit compensation expense - -
Gain on sale of North Louisiana disposal group 217 0.00
Debt extinguishment costs   -     -  
Adjusted income (loss) before tax effect 56,343 0.57
Tax effect related to adjustments   (6,554 )   (0.07 )
Adjusted income (loss) after tax effect   49,789     0.50  
Preferred stock dividend 6,756 0.07
Undistributed earnings allocated to participating securities   1,233     0.01  
Adjusted net income (loss) 57,778 0.58
Preferred stock dividend (6,756 ) (0.07 )
Undistributed adjusted earnings allocated to participating securities   (13,198 )   (0.13 )
Adjusted net income (loss) available to common shareholders $ 37,824   $ 0.38  
 
Weighted average basic and diluted shares outstanding 99,639
 

Calculation of Net Debt:

Net Debt is a supplemental non-GAAP financial measure that is used by
external users of WRD's financial statements. We define Net Debt as
total debt minus cash and cash equivalents. We believe Net Debt is
useful to investors because it provides readers with a more meaningful
measure of our outstanding indebtedness. However, this measure is
provided in addition to, not as an alternative for, and should be read
in conjunction with, the information contained in our financial
statements prepared in accordance with GAAP.

GP&T and Revenue Recognition Reconciliation – Third Quarter 2018

The table below reconciles revenue and gathering, processing and
transportation expense to the reporting convention prior to the
implementation of the new FASB revenue recognition standard on January
1, 2018 (ASC 606, Revenue from Contracts with Customers). For additional
information on the GP&T reconciliation and the new revenue recognition
standard, see the Management's Discussion & Analysis section of WRD's
third quarter 2018 10-Q to be filed on or before November 9, 2018.

                       
Prior Reporting Variance

New FASB Revenue
Recognition Standard

Guidance
(prior reporting)

Revenues:
Oil revenue $236,056 ($16) $236,040
Gas revenue $10,378 ($1,080) $9,298
NGL revenue $16,125 ($2,242) $13,883
Other Income $269 $0 $269
 
Natural gas price realization (% of Henry Hub) 90% -10% 80% 90% - 94%
NGL price realization (% of WTI) 41% -6% 35% 33% - 37%
 
Operating expenses:
Lease operating expenses $14,681 ($460) $14,221
GP&T expense $6,246 ($3,021) $3,225
Depreciation, depletion, and amortization $75,023 ($181) $74,842
Other operating (income) expense $1 $168 $169
 
GP&T per boe $1.39 ($0.67) $0.72 $1.10 - $1.40

View Comments and Join the Discussion!