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WildHorse Resource Development Corporation Announces Second Quarter Results

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

  • Increased average daily production by 107% to 46.7 Mboe/d for the
    second quarter 2018 compared to 22.6 Mboe/d for the second quarter 2017
  • Brought online 28 gross (26.2 net) Eagle Ford wells in the second
    quarter of 2018
  • Crude oil realizations in the second quarter of 2018 were 100% of WTI
    as a result of low differentials and favorable Louisiana Light Sweet
    ("LLS") pricing
  • The Irene/Inez/Lero Eagle Ford wells, located in Brazos County and
    previously announced in first quarter 2018, reached their average
    final peak IP-30(1) of 788 Boe/d (89% oil) on an average
    6,404' lateral
  • The JRG C 1H, an Austin Chalk well in southern Burleson County brought
    online at the end of the first quarter, reached a peak IP-30(1) of
    747 Boe/d (43% natural gas, 45% NGLs and 12% oil) on a 5,843' lateral

Financial highlights from second quarter 2018 and other recent
highlights include:

  • Reported a Net Loss of $14.1 million for the second quarter 2018
  • Reported a Net Loss available to common stockholders of $22.1 million
    or $0.22 per share for the second quarter 2018
    • Reported Adjusted Net Income available to common stockholders(2)
      of $39.1 million or $0.39 per share for the second quarter 2018
    • Reported Adjusted EBITDAX(2) of $161.5 million for the
      second quarter 2018
  • Issued an additional $200 million of 6.875% Senior Notes due 2025 in
    April 2018

"In the second quarter, WRD delivered excellent results which were
amplified by the strength of our takeaway capabilities and LLS pricing.
We are currently on track to meet or exceed the midpoint of our annual
guidance," said Jay Graham, Chairman and Chief Executive Officer of WRD.
"In addition, WRD is on schedule to start our in-field sand mine by the
first quarter of 2019. We have received all of the necessary permits for
the mine and are in the process of installing the plants and facilities.
WRD is in an enviable position with our Gulf Coast location, access to
premium markets, and reduced well costs with the completion of our sand
mine. We look forward to leveraging this unique position to drive full
cycle returns and create value for our shareholders."

Second Quarter 2018 Results

Net production was 46.7 Mboe/d for the second quarter 2018 compared to
22.6 Mboe/d for the second quarter 2017. Second quarter 2018 net
production consisted of approximately 33.4 Mbbls/d oil, 6.0 Mboe/d NGLs,
and 43.5 MMcf/d natural gas.

WRD reported a Net Loss of $14.1 million for the second quarter 2018.
The Net Loss available to common stockholders was $22.1 million or $0.22
per share for the second quarter 2018. Earnings in the second quarter
were impacted by a $13.8 million non-cash contribution to shareholder's
equity related to Natural Gas Partner's distribution of WRD shares in
May 2018, which is also recognized on the incentive unit compensation
expense line of the income statement.

Adjusted Net Income available to common stockholders(2) for
the second quarter 2018 was $39.1 million or $0.39 per share. WRD
reported Adjusted EBITDAX(2) for the second quarter 2018 of
$161.5 million compared to Adjusted EBITDAX(2) for the second
quarter 2017 of $52.4 million.

Total revenues and other income for the second quarter 2018, excluding
the impact of realized hedges, were $225.4 million compared to $70.2
million for the second quarter 2017. Total revenues were primarily
higher as a result of increased production and higher commodity prices.
Crude oil price realizations were 100% of WTI as a result of low
transportation differential and favorable LLS pricing. Natural gas
realizations were lower than previous quarters at 73% of Henry Hub as a
result of the North Louisiana asset divestiture which had higher gas
realizations. Also, in comparison to North Louisiana, the structure of
WRD's gas contracts in the Eagle Ford allocates a greater portion of
gathering costs to revenue deductions rather than GP&T expenses
following the new FASB revenue recognition standard (ASC 606, Revenue
from Contracts with Customers).

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

           
Percent
Q2'18 Q2'17 Change
Oil (per Bbl) $ 68.21 $ 46.77 46 %
Natural Gas (per Mcf) $ 2.05 $ 3.09 -34 %
NGL (per BbL) $ 17.59 $ 16.59 6 %
Total (per Boe) $ 52.99 $ 33.90 56 %
 

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

           
Percent
Q2'18 Q2'17 Change
Oil (per Bbl) $ 57.49 $ 49.80 15 %
Natural Gas (per Mcf) $ 2.02 $ 3.07 -34 %
NGL (per BbL) $ 17.59 $ 16.59 6 %
Total (per Boe) $ 45.30 $ 35.54 27 %
 

Lease operating expense ("LOE") for the second quarter 2018 was $12.1
million, or $2.84 per Boe, compared to $6.8 million, or $3.33 per Boe,
for the second quarter 2017. The decline in LOE was the result of
optimized chemicals usage and more favorable procurement and labor
contracts.

Depletion, depreciation, and amortization ("DD&A") for the second
quarter 2018 was higher at $70.7 million or $16.64 per boe in comparison
to $59.9 million or $12.70 per boe during the first quarter 2018. In the
first quarter, DD&A for North Louisiana was accounted for until the
execution of the definitive North Louisiana purchase and sale agreement
on February 12, 2018. Due to this effect, DD&A on a boe basis was lower
in the first quarter of 2018. In addition, the DD&A rate in the Eagle
Ford was higher in the second quarter of 2018. As a result, higher
second quarter DD&A negatively impacted our net income relative to
expectations based on the first quarter DD&A rate.

Gathering, processing and transportation expense ("GP&T") for the second
quarter 2018 was $0.5 million, or $0.11 per Boe, compared to $1.9
million, or $0.95 per Boe, in the second quarter 2017. GP&T 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 our 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 second quarter 2018 Form 10-Q for a reconciliation of GP&T and
pricing realizations to the previous accounting convention.

Taxes other than income were $12.8 million for the second quarter 2018,
or $3.01 per Boe, compared to $4.5 million, or $2.20 per Boe, for the
second quarter 2017. Taxes other than income in the second quarter 2018
increased primarily due to higher price realizations and changes in the
commodity mix.

General and administrative ("G&A") expense for the second quarter 2018
was $12.9 million, or $3.04 per Boe, compared to $10.0 million, or $4.89
per Boe, for the second quarter 2017. Reported G&A expense is net of
$1.0 million due from Tanos Exploration for transitional services in
connection with the purchase of the North Louisiana assets. During the
second quarter 2018, G&A expense included $3.8 million, or $0.90 per
Boe, of stock-based compensation expense and $0.1 million, or $0.03 per
Boe, of acquisition related costs. Excluding acquisition related costs,
cash G&A expense(2), which does not include stock-based
compensation, was $9.0 million or $2.11 per Boe for the second quarter
2018.

Exploration expense was $4.4 million for the second quarter 2018
compared to $11.5 million for the second quarter 2017. Exploration
expense in the second quarter reflects a decrease in seismic acquisition
costs and abandonment costs.

Net interest expense during the second quarter 2018 was $14.0 million,
including amortization of deferred financing fees of approximately $0.8
million. This compares to net interest expense during the second quarter
2017 of $6.6 million, including amortization of deferred financing fees
of approximately $0.4 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 2017 and April 2018.

Drilling and completion ("D&C") capital expenditures totaled $233.3
million in the second quarter 2018 and $450.0 million for the first half
of 2018 which is in line with WRD's front-weighted capital budget
program. Sand mine expenditures totaled $15.8 million in the second
quarter 2018 and $25.1 million for the first half of 2018.

     

(1)

  The initial production rates represent the peak average of the
initial production rates for the applicable consecutive days 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 second quarter 2018 average daily production of 46.7 Mboe/d
consisting of 72% oil, 15% natural gas, and 13% NGLs. WRD brought online
a total of 28 gross (26.2 net) Eagle Ford wells and 5 Eagle Ford refracs
in the second quarter 2018.

In the Eagle Ford, the Irene, Inez, and Lero wells, brought online late
in the first quarter in Brazos County have reached their average final
IP-30 rate(1) of 788 Boe/d (89% oil) on an average 6,404'
lateral.

In the Austin Chalk, the JRG C 1H, a well located in southern Burleson
County brought online at the end of the first quarter, reached a peak
IP-30(1) of 747 Boe/d (43% natural gas, 45% NGLs and 12% oil)
on a 5,843' lateral. WRD brought online no new Austin Chalk wells in the
second quarter but expects to bring online four Austin Chalk wells in
the third quarter or early fourth quarter of 2018 depending on timing.

Financial Update

In April 2018, WRD issued an additional $200 million of 6.875% Senior
Notes due 2025. In addition, Moody's increased WRD's Long Term Corporate
Family Rating to B2 with a positive outlook from B3 with a stable
outlook during the second quarter of 2018. Total net debt(2)
outstanding as of June 30, 2018 was $930 million, including $249 million
of debt outstanding under WRD's revolving credit facility, $700 million
of Senior Notes due 2025, and $19 million in cash and cash equivalents.
As of June 30, 2018, WRD's liquidity was $820 million consisting of $19
million of cash and cash equivalents and $801 million of availability
under its revolving credit facility. The next redetermination of the
borrowing base utilizing mid-year 2018 reserves is scheduled for October
2018.

WRD's net debt(2) to annualized second quarter 2018 Adjusted
EBITDAX(2) ratio was 1.4 times. WRD continues to target a net
debt(2) to quarterly annualized Adjusted EBITDAX(2)
ratio below 2.0 times based on the mid-point of guidance. WRD expects
the available borrowings under its revolving credit facility to provide
sufficient liquidity to finance anticipated working capital and capital
expenditure requirements.

Hedging Update

WRD utilizes its hedging program to mitigate financial risks and the
effects of commodity price volatility. Total hedged production in the
second quarter of 2018 was approximately 2.6 MMboe, or 62% of second
quarter production of 4.2 MMboe. As of August 7, 2018, WRD had hedged
approximately 65% of its remaining 2018 production on a barrel of oil
equivalent basis (using the mid-point of WRD's annual guidance range).

In the second quarter, WRD entered into additional natural gas contracts
extending to 2020. Specifically, WRD hedged approximately 22.4 billion
cubic feet of natural gas distributed across 2018 to 2020 at
approximately $2.79 per Mcfe. In addition, during the second quarter,
WRD added 3.4 MMbls of oil swaps out to 2020 and also added 1.9 MMbls of
oil basis hedges on average locking in a LLS premium to WTI of
approximately $3.01 per Bbl for the remainder of 2018. With a
combination of puts and unhedged production, WRD maintains upside on
approximately 52% of its remaining 2018 oil production.

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

           
Q3 - Q4 '18     2019     2020
 
Crude Oil Hedge Contracts:
Total crude oil volumes hedged (Bbl) 4,614,905 8,402,126 4,511,681
Volumes hedged (Bbl/d) 25,081 23,020 12,327
Total weighted-average price $ 51.53 $ 54.32 $ 53.49
Expected crude production hedged (3) 75% - -
 
Natural Gas Hedge Contracts:
Total natural gas volumes hedged (MMbtu) 4,723,634 6,425,146 4,846,020
Volumes hedged (MMbtu/d) 25,672 17,603 13,240
Total weighted-average price $ 2.79 $ 2.79 $ 2.76
Expected gas production hedged (3) 86% - -
 
Total Hedge Contracts:
Total hedged production (boe) 5,402,177 9,472,984 5,319,351
Volumes hedged (Boe/d) 29,360 25,953 14,534
Total weighted-average price ($/boe) $ 44.43 $ 48.49 $ 45.79
Expected total production hedged (3) 65% - -
 
LLS Basis Swaps
Total crude oil volumes hedged (Bbl) 3,339,230 - -
Volumes hedged (Bbl/d) 18,148 - -
Total weighted-average price - WTI to LLS $ 3.02 - -
Expected crude production hedged (3) 54% - -
 

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

 

Upcoming Conferences

Members of WRD's management team intend to participate in the following
upcoming investment conferences:

  • EnerCom Oil & Gas Conference on August 20 – 21, 2018 (Denver, CO)
  • Simmons European Energy Conference on August 28 – 29, 2018
    (Gleneagles, Scotland)
  • Seaport Global Chicago Energy Conference on August 28 – 29, 2018
    (Chicago, IL)
  • Barclays CEO Energy-Power Conference on September 4 – 5, 2018 (New
    York, NY)
  • Johnson Rice 2018 Energy Conference on September 24 – 26, 2018 (New
    Orleans, LA)

Presentation materials for all conferences mentioned above will be
available on WRD's website at www.wildhorserd.com on or prior to the day
of the respective presentation.

Quarterly Report on Form 10-Q

WRD's financial statements and related footnotes will be available in
its Quarterly Report on Form 10-Q for the quarter ended June 30, 2018,
which will be filed with the U.S. Securities and Exchange Commission
("SEC") on or before August 9, 2018.

Conference Call and Webcast

WRD will host an investor conference call tomorrow morning, August 8,
2018 at 8 a.m. Central (9 a.m. Eastern) to discuss the second quarter
2018 operating and financial results. Interested parties are invited to
participate on the call by dialing (877) 883-0383 (Conference ID:
9209183), or (412) 902-6506 for international calls, (Conference ID:
9209183) at least 15 minutes prior to the start of the call or via the
internet at www.wildhorserd.com. A replay of the call will be available
on WRD's website or by phone at (877) 344-7529 (Conference ID: 10121205)
for a seven-day period following the call.

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.

Cautionary Statements and Additional Disclosures

This press release includes "forward-looking statements" within the
meaning of Section 27A of the Securities Act of 1933, as amended, and
Section 21E of the Securities Exchange Act of 1934, as amended.
Forward-looking statements can be identified by words such as
"anticipates," "intends," "will," "plans," "seeks," "believes,"
"estimates," "could," "expects" and similar references to future
periods. Such forward-looking statements are subject to a number of
risks and uncertainties, many of which are beyond WRD's control. All
statements, other than historical facts included in this press release,
that address activities, events or developments that WRD expects or
anticipates will or may occur in the future, including such things as
WRD's future capital expenditures (including the amount and nature
thereof), business strategy and measures to implement strategy, future
drilling locations and inventory, 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 such matters are
forward-looking statements. All forward-looking statements speak only as
of the date of this press release. Although WRD believes that the plans,
intentions and expectations reflected in or suggested by the
forward-looking statements are reasonable, there is no assurance that
these plans, intentions or expectations will be achieved. Therefore,
actual outcomes and results could materially differ from what is
expressed, implied or forecast in such statements.

WRD cautions you that these forward-looking statements are subject to
risks and uncertainties, most of which are difficult to predict and many
of which are beyond WRD's control, incident to the exploration for and
development, production, gathering and sale of natural gas and oil.
These risks include, but are not limited to: commodity price volatility;
inflation; lack of availability of drilling and production equipment and
services; environmental risks; drilling and other operating risks;
regulatory changes; the uncertainty inherent in estimating natural gas
and oil reserves and in projecting future rates of production, cash flow
and access to capital; and the timing of development expenditures.
Information concerning these and other factors can be found in WRD's
filings with the SEC, including its Forms 10-K, 10-Q and 8-K.
Consequently, all of the forward-looking statements made in this press
release are qualified by these cautionary statements and there can be no
assurances that the actual results or developments anticipated by WRD
will be realized, or even if realized, that they will have the expected
consequences to or effects on WRD, its business or operations. WRD has
no intention, and disclaims any obligation, to update or revise any
forward-looking statements, whether as a result of new information,
future results or otherwise.

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.

Management Locations

WRD has a total of 3,207 net horizontal drilling locations in the
proved, probable, and possible categories as audited by CG&A, WRD's
third party engineers, which also includes 446 net locations that have
been identified by WRD's management. WRD identified those additional
locations using the same methodology as those locations to which
probable and possible reserves are attributed—by using existing geologic
and engineering data from vertical production and seismic data. Of WRD's
total 3,207 net horizontal drilling locations, 2,761 lie within the
geographic areas to which proved, probable and possible reserves are
attributed by CG&A. The remaining 446 management identified net
horizontal drilling locations are within geographic areas to which
proved, probable or possible reserves are not attributed, but
nonetheless are locations that WRD has specifically identified based on
its evaluation of applicable geologic and engineering data accrued over
our multi-year historical drilling activities in the surrounding area.
The management location count includes 110 net locations from the Lee
County, TX acquisition which closed on March 1, 2018. The locations have
been identified by WRD's management based on its evaluation of
applicable geologic and engineering data from historical drilling
activities in the surrounding area. The locations on which WRD actually
drills wells will ultimately depend upon the availability of capital,
regulatory approvals, seasonal restrictions, oil and natural gas prices,
costs, actual drilling results and other factors, and may differ from
the locations currently identified.

                 
Net Locations CG&A Management Total
Dec. 31, 2017 Locations Locations(4)

Locations

Eagle Ford 2,708 445 3,154
Austin Chalk 53 0 53
Total Locations 2,761 446 3,207
 

(4) Includes 110 net locations from the Lee County, TX acquisition
which closed on March 1, 2018.

 

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 June 30,
(Amounts in $000s except per share data) 2018 2017

Revenues and other income:

Oil sales $ 207,392 $ 52,963
Natural gas sales 8,106 13,277
NGL sales 9,668 3,404
Other income   247         529  
Total operating revenues and other income   225,413         70,173  
 

Operating Expenses:

Lease operating expenses 12,088 6,837
Gathering, processing and transportation 476 1,942
Taxes other than income 12,779 4,509
Depreciation, depletion and amortization 70,694 33,229
General and administrative expenses 12,917 10,049
Exploration expense 4,369 11,504
Incentive unit compensation expense 13,776 -
(Gain) loss on sale of properties (3,167 ) -
Other operating (income) expense   111         25  
Total expenses   124,043         68,095  
 
Income (loss) from operations 101,370 2,078
 

Other Income (Expense):

Interest expense (14,002 ) (6,633 )
Debt extinguishment costs - -
Gain (loss) on derivative instruments (110,805 ) 46,116
Other income (expense)   (13 )       (2 )
Total other income (expense)   (124,820 )       39,481  
 
Income (loss) before income taxes (23,450 ) 41,559
Income tax benefit (expense)   9,356         (15,193 )
Net Income (loss)   (14,094 )       26,366  
Preferred stock dividends 7,961 73
Undistributed earnings allocated to participating securities   -         387  
Net income (loss) available to common stockholders $ (22,055 )     $ 25,906  
 
Earnings per share
Basic $ (0.22 ) 0.28
Diluted $ (0.22 ) 0.28
 
Weighted average shares outstanding
Basic 99,411 93,685
Diluted 99,411 93,685
   

WildHorse Resource Development Corporation

Statements of Condensed Consolidated Cash Flows

 
For the Three Months
Ended June 30,
(Amounts in $000s) 2018     2017
 
Cash flows from operating activities:
Net Income (Loss) $ (14,094 ) $ 26,366
Adjustments to reconcile net income (loss) to cash flows
provided by operating activities
Depreciation, depletion and amortization 70,579 33,074
Accretion of asset retirement obligations 115 155
Impairments of unproved properties 4,359 9,980
Amortization of debt issuance costs 768 439
Accretion of senior note discount premium (35 ) 63
(Gain) loss on derivative instruments 110,805 (46,116 )
Cash settlements on derivative instruments (29,508 ) 2,076
Consideration paid to customers, net of amortization (904 ) -
Deferred income tax expense (benefit) (12,800 ) 15,193
Non-cash incentive unit compensation expense 13,776 -
Amortization of equity awards 3,835 1,308
(Gain) loss on sale of properties (3,167 ) -
Changes in operating assets and liabilities   29,809     1,677  
Net cash provided by operating activities   173,538     44,215  
 
Cash flows from investing activities:
Net cash used in investing activities   (292,252 )   (699,543 )
 
Cash flows from financing activities:
Net cash provided by financing activities   130,836     576,619  
 
Net change in cash, cash equivalents, and restricted cash $ 12,122 $ (78,709 )
Cash, cash equivalents and restricted cash, beginning of period   7,017     94,094  
Cash, cash equivalents and restricted cash, end of period $ 19,139   $ 15,385  
 

WildHorse Resource Development Corporation

Operating Data

 
      For the Three Months
Ended June 30,
2018       2017

Production volumes

Oil Sales (MBbls) 3,041 1,133
Natural Gas Sales (MMcf) 3,954 4,299
NGL Sales (MBbls)   550   205
Total (Mboe) 4,249 2,054
Total (Mboe/d) 46.7 22.6
 

Average unit costs per boe

Lease operating expense $ 2.84 $ 3.33
Gathering, processing and transportation $ 0.11 $ 0.95
Taxes other than income $ 3.01 $ 2.20
General and administrative expenses $ 3.04 $ 4.89
Cash General and administrative expenses $ 2.14 $ 4.26
Acquisition-related expenses $ 0.03 $ 1.07
             

WildHorse Resource Development Corporation

Condensed Consolidated Balance Sheets

 
June 30,         December 31,
(Amounts in $000s) 2018 2017
 
ASSETS
Current Assets:
Cash and cash equivalents $ 19,139 $ 226
Accounts receivable, net 109,017 84,103
Derivative instruments - 2,336
Prepaid expenses and other current assets     4,669     3,290  
Total Current Assets 132,825 89,955
 
Property & equipment:
Oil and natural gas properties 3,007,462 2,999,728
Other property and equipment 53,124 53,003
Accumulated depreciation, depletion and impairment     (351,248 )   (368,245 )
Total property and equipment, net 2,709,338 2,684,486
 
Other noncurrent assets
Derivative instruments 491 86
Debt issuance costs 3,618 3,573
Other     13,256     -  
Total Assets   $ 2,859,528   $ 2,778,100  
 
LIABILITIES AND EQUITY
Current Liabilities:
Accounts payable $ 65,710 $ 53,005
Accrued liabilities 193,552 199,952
Short-term derivative instruments     107,206     58,074  
Total Current Liabilities 366,468 311,031
 
Noncurrent Liabilities:
Long-term debt 935,609 770,596
Asset retirement obligations 7,518 14,467
Deferred tax liabilities 20,612 71,470
Derivative instruments 61,866 18,676
Other noncurrent liabilities     874     1,085  
Total liabilities 1,392,947 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 1,141,140 1,118,507
Accumulated earnings (deficit)     (123,305 )   25,773  
Total stockholders' equity 1,018,855 1,145,292
     
Total Liabilities & Equity   $ 2,859,528   $ 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 August 7, 2018:

 
Q2 - Q4 '18 2019 2020
Crude Oil Derivative Contracts:
Swap contracts:
Volume (Bbl) 2,958,527 6,652,369 4,511,681
Weighted-average fixed price $52.36 $54.45 $53.49
 
Deferred put options
Volume (Bbl) 1,656,378 1,749,757 -
Weighted-average floor price $50.04 $53.83 -
Weighted-average put premium

($3.64)

($5.43) -
 
LLS basis swaps
Volume (Bbl) 3,339,230 - -
Weighted-average fixed price - WTI to LLS $3.02 - -
 
 
Natural Gas Derivative Contracts:
Swap contracts:
Volume (MMBtu) 4,723,634 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 June 30,
(Amounts in $000s) 2018 2017
Net Income (Loss) $ (14,094 ) $ 26,366

Add (Deduct):

Interest expense, net 14,002 6,633
Income tax (benefit) expense (9,356 ) 15,193
Depreciation, depletion and amortization 70,694 33,229
Exploration expense 4,369 11,504
(Gain) loss on derivative instruments 110,805 (46,116 )
Cash settlements received / (paid) on commodity derivatives (29,508 ) 2,076
Stock-based compensation 3,835 1,308
Incentive unit compensation 13,776 -
Acquisition related costs 129 2,199
Gain on sale of North Louisiana disposal group (3,167 ) -
Debt Extinguishment costs   -       -  
Adjusted EBITDAX $ 161,485     $ 52,392  
 

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 June 30, 2018
(Amounts in $000s)     (Basic / Diluted EPS)
 
Net Income (Loss) available to common stockholders $ (22,055 ) ($0.22 )
 
Add (Deduct)
(Gain) loss on derivative instruments 110,805 1.11
Cash settlements received / (paid) on commodity derivatives (29,508 ) (0.30 )
Stock-based compensation 3,835 0.04
Impairment of oil and gas properties - -
Incentive unit compensation expense 13,776 0.14
Gain on sale of North Louisiana disposal group (3,167 ) (0.03 )
Debt extinguishment costs   -     -  
Adjusted income (loss) before tax effect 73,686 0.74
Tax effect related to adjustments   (20,929 )   (0.21 )
Adjusted income (loss) after tax effect   52,757     0.53  
Preferred stock dividend 7,961 0.08
Undistributed earnings allocated to participating securities   -     -  
Adjusted net income (loss) 60,718 0.61
Preferred stock dividend (7,961 ) (0.08 )
Undistributed adjusted earnings allocated to participating securities   (13,615 )   (0.14 )
Adjusted net income (loss) available to common shareholders $ 39,142   $ 0.39  
 
Weighted average basic and diluted shares outstanding 99,411
 

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 – Second 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
second quarter 2018 10-Q to be filed on or before August 9, 2018.

                       
Prior Reporting Variance

New FASB Revenue
Recognition Standard

Guidance
(prior reporting}

Revenues:
Gas revenue $9,540 ($1,434) $8,106
NGL revenue $12,193 ($2,525) $9,668
Other Income $304 ($57) $247
 
Natural gas price realization (% of Henry Hub) 86% -13% 73% 90% - 94%
NGL price realization (% of WTI) 33% -7% 26% 33% - 37%
 
Operating expenses:
Lease operating expenses $12,395 ($307) $12,088
GP&T expense $4,022 ($3,546) $476
Depreciation, depletion, and amortization $70,849 ($155) $70,694
Other operating (income) expense $282 ($171) $111
 
GP&T per boe $0.95 ($0.84) $0.11 $1.10 - $1.40

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