OKLAHOMA CITY, May 10, 2017 /PRNewswire/ -- SandRidge
Energy, Inc. (the "Company" or "SandRidge") (NYSE:SD) today
announced financial and operational results for the quarter ended
March 31, 2017. Additionally, the
Company will host a conference call to discuss these results on
May 11 at 8:00
a.m. CT (877-201-0168, International: 647-788-4901 –
passcode: 4580429). Presentation slides will be available on the
Company's website, www.sandridgeenergy.com, under Investor
Relations/Events.
The Company reported net income of $51
million, or $1.90 per share,
and net cash from operating activities of $64 million for the first quarter of 2017. When
adjusting these reported amounts for items that are typically
excluded by the investment community on the basis that such items
affect the comparability of results, the Company's "adjusted net
income" amounted to $21 million, or
$0.78 per share, and "adjusted
operating cash flow" totaled $53
million. Earnings before interest, income taxes,
depreciation, depletion, and amortization, adjusted for certain
other items, otherwise referred to as "adjusted EBITDA" for the
first quarter was $56
million.(1)
(1)
|
The Company has
defined and reconciled certain Non-GAAP financial measures
including adjusted net income, adjusted operating cash flow,
adjusted EBITDA, and current net debt, to the most directly
comparable GAAP financial measures in supporting tables at the
conclusion of this press release under the "Non-GAAP Financial
Measures" beginning on page 13.
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Production for the quarter was 4.0 MMBoe (28% oil, 22% NGLs and
50% natural gas). The Company's Mid-Continent assets produced
approximately 92% of total production (23% oil), while the
North Park Basin (NPB) of
Colorado provided 4% (100% oil)
and the Permian Basin 3% (82% oil). The Company had one active rig
drilling in the NW STACK area of Oklahoma for most of the first quarter, and
added a second rig there in mid-March. Near term drilling will
focus on the NW STACK and North
Park Basin Niobrara, which produce oil in excess of 50% and
90% of total production, respectively. With more wells being
drilled and brought to sales throughout the year in these two
plays, crude oil, as a proportion of total production, is expected
to increase from 28% in the first quarter to over 30% in the fourth
quarter of 2017.
Total lifting costs during the quarter were $7.08 per boe, including lease operating expenses
of $6.28 per boe. The Company
continues to gain operating efficiencies with a recent focus on
chemical treatment optimization and electrical power contract
pricing. Decreases in overall expenses were partly offset by above
average costs in Colorado due to
severe winter weather.
James Bennett, SandRidge
President and CEO said, "Motivated by our recent successes in
the NW STACK, we now have two rigs developing the Meramec in
Major, Woodward and Garfield Counties, where we have 70,000 net
acres. Low cost drilling, operational efficiencies and innovations
established in our Mississippian program will benefit us as they
are applied across our portfolio. Our Colorado North Park Basin
drilling will resume at midyear with one rig. Plans there include
more Niobrara extended laterals and drilling on our newly
established 24,000 acre Federal Unit. The development of our
oil-weighted NW STACK and North
Park Basin Niobrara projects is creating material resource
value and will drive oil production growth later in 2017. Supported
by the flexibility of our unlevered balance sheet and $550 million of liquidity, we believe SandRidge
has a compelling multiyear story."
Highlights during the first quarter include:
$51 Million of Net Income
and $56 Million of Adjusted
EBITDA
$41 Million of Capex During
the Quarter (Excluding Previously Disclosed ~13,100 Net Acre NW
STACK Acquisition)
Incremental Leasehold Additions Totaling 10,000 Net Acres
Bring NW STACK Position to 70,000 Net Acres
Two Rigs Targeting Meramec in NW STACK
Q1'17 Production of 4.0 MMBoe (28% Oil, 22% NGLs and 50%
Natural Gas)
Mississippian Full Section Development Multilateral (Three
Lateral Equivalent), the Hawk Haven 2710 1-22H, Produced Combined
30-Day IP of 1,248 Boepd (47% Oil) at Drilling and Completion Costs
of $5.5 Million or $1.8 Million per Lateral
2017 Capital Budget
The Company is reiterating prior capital spending guidance,
expecting to invest between $210 and $220
million in 2017. This level of activity supports projected
oil production growth in the second half of 2017. Depending on well
results and commodity pricing, capital spending plans may be
revised later in the year.
Two drilling rigs are currently active in the NW STACK play in
Major, Woodward and Garfield Counties, Oklahoma. The Company plans to drill 22 gross
laterals (17 net) in the Meramec and six laterals (gross and net)
in the North Park Niobrara during 2017, predominantly drilling
extended reach laterals.
Mid-Continent Assets in Oklahoma
- First quarter production of 3.7 MMBoe, (40.8 MBoepd, 23% oil,
24% NGLs, 53% natural gas)
- Drilled two laterals in
the first quarter and brought three laterals online
- Incremental leasehold additions totaling 10,000 net acres bring
current NW STACK position to 70,000 net acres
- Mississippian full section development multilateral, the Hawk
Haven 2710 1-22H, produced a combined 30-Day IP of 1,248 Boepd or
416 Boepd per lateral equivalent (47% oil), drilled and completed
for $5.5 million ($1.8 million per lateral)
- Currently running two rigs targeting Meramec in NW STACK
- Four Meramec extended reach wells currently in progress: one
flowing back, one completing and two drilling
- Acquired rights to 329 square
mile 3D seismic survey to further enhance NW STACK reservoir
characterization
SandRidge is well established as the low-cost driller of
Mississippian wells and expects to transfer capabilities and best
practices, including ongoing application of extended reach lateral
drilling, to become a low-cost leader in the adjacent NW STACK play
as well.
Drilling activity has continued on Meramec targets following the
success of the previously announced Medill 1-27H well in
Major County, Oklahoma (30-Day IP
of 925 Boepd, 77% oil and currently producing ~460 Boepd, with
cumulative production of 99 MBoe after 140 days, 99% above type
curve).
Additional wells were spud and drilling continued at the end of
the quarter in Major County,
including the Campbell 2015 1-26H23H, the Company's first Meramec
extended reach well drilled in Major
County, offset to the Medill. Drilling was also underway in
Garfield County with the Landrum
2305 1-30H31H, a Meramec extended
reach well near existing SandRidge Meramec and Osage production. Both of these wells should
have 30-Day initial production rates reported in the second
quarter.
The Adams 2122 1-16H9H extended
reach well targeting the Meramec in Woodward County was undergoing completion
operations at the end of the first quarter, with a 30-Day initial
production rate to be reported in the second quarter earnings
release.
During the first quarter, the Company acquired ~13,100 net acres
and 700 Boepd of production in the NW STACK of Oklahoma for $48
million of cash. The first new well on the acquired acreage
will be spud during the second quarter of 2017.
Niobrara Asset in North Park
Basin, Jackson County,
Colorado
- First quarter production of 173 MBo (1.9 MBopd)
- Drilling activity to resume at midyear with current plans to
have one rig targeting multiple Niobrara benches
- Average cumulative oil production as of May 4 from all wells drilled in 2016 exceeds type
curve by 11%
- First "C" bench well, the Hebron 4-18H, (30-Day IP of 539 Boepd, 92%
oil) produced cumulative oil of 70 MBo after 170 producing days.
This volume is 32% higher than type curve and is the strongest
single lateral of the 2016 program.
- Peterson Ridge and Rabbit Ears
3D seismic survey completed (61 square miles), increasing total NPB
3D seismic coverage to 115 square miles
- Extension of current oil transportation and marketing agreement
continues ~$3.15/ bbl WTI
differential through the end of 2018
North Park Basin drilling
activity will resume midyear with three extended reach wells
planned (equivalent to six laterals). In addition to continued "D"
bench development, the Company will drill an extended lateral well
targeting the "C" bench following excellent results from the
Hebron 4-18H, the first "C" bench
single lateral well drilled in 2016. The Hebron 4-18H, the Company's most productive
single lateral in 2016, yielded a 30-Day IP of 539 Boepd, 92% of
which was oil, and 70 MBo in its first six months of production,
32% above type curve. 2017 drilling will also include a
Niobrara well in the newly established 24,000 net acre Rabbit Ears
Federal Unit and the Company's first well targeting the thick B
bench of the Niobrara.
Following encouraging results from the Company's 2016 drilling
program, specific technical goals have been developed for the 2017
program to enhance reservoir characterization with the integration
of newly acquired 3D seismic data, coring of multiple Niobrara
benches and expanded logging suites.
The Company is currently assessing in-field gas processing (such
as the use of mechanical refrigeration units), gas-to-liquids and
gas reinjection, with the potential to generate additional revenue
streams and reduce combusted gas volumes.
Other Operational Activities
During the first quarter,
Permian Central Basin Platform properties produced 136 MBoe (1.5
MBoepd, 82% oil, 11% NGLs, 7% natural gas).
Key Financial Highlights and Results
First Quarter Results
- Net Income of $51 million, or
$1.90 per share, for first quarter
2017 compared to a $324 million loss
in first quarter of 2016
- Adjusted EBITDA was $56 million
for first quarter 2017 compared to $42
million in first quarter 2016, pro forma for
divestitures
- Adjusted net income of $21
million, or $0.78 per share,
for first quarter 2017 compared to an adjusted net loss of
$81 million in first quarter 2016
- Net cash provided from operating activities of $64 million for first quarter of 2017 compared to
$163 million used in first quarter of
2016
- Adjusted operating cash flow of $53
million for first quarter 2017 compared to negative
$111 million in first quarter
2016
Capitalization & Liquidity
- 35.9 million shares outstanding
- $600 million reserve-based credit
facility with $425 million borrowing
base
- Liquidity of $554 million
including $137 million of cash and
$417 million capacity under the
credit facility, net of outstanding letters of credit
- Outstanding debt consists of a $38
million note secured by the Company's real estate, resulting
in zero current net debt
Entering into the new credit facility in February 2017 triggered the release of
$50 million of cash held in escrow to
the Company and the conversion of all of the $264 million outstanding mandatorily convertible
notes into approximately 14.1 million shares of the Company's
common stock.
Hedging
Unchanged from the previous reporting period, in 2017 the
Company has approximately 3.3 million barrels of oil hedged at an
average WTI price of $52.24 as well
as 32.9 billion cubic feet of natural gas hedged at an average
price of $3.20 per MMBtu. 2017 oil
hedges represent 80% of the midpoint of current oil volume
guidance. 2017 gas hedges represent 77% of the midpoint of current
gas volume guidance.
For 2018, the Company has approximately 1.8 million barrels of
oil hedged at an average WTI price of $55.34. Subsequent to the first quarter, 9.1
billion cubic feet of natural gas swaps were added, bringing the
total to approximately 12.8 billion cubic feet of natural gas
hedged at an average price of $3.16
per MMBtu in 2018.
Conference Call Information
The Company will host a conference call to discuss these results
on Thursday, May 11, 2017 at
8:00 am CDT. The telephone number to
access the conference call from within the U.S. is (877)
201-0168 and from outside the U.S. is (647) 788-4901. The
passcode for the call is 4580429. An audio replay of the call will
be available from May 11, 2017 until
11:59 pm CDT on June 11, 2017. The number to access the
conference call replay from within the U.S. is (800) 585-8367 and
from outside the U.S. is (416) 621-4642. The passcode for the
replay is 4580429.
A live audio webcast of the conference call will also be
available via SandRidge's website, www.sandridgeenergy.com, under
Investor Relations/Events. The webcast will be archived for replay
on the Company's website for 30 days.
2017 Capital Expenditure and Operational
Guidance
Presented below is the Company's capital expenditure and
operational guidance for 2017. This information is unchanged from
the initial release on February 22,
2017.
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|
|
|
|
|
|
Total
Company
|
|
|
|
|
|
Projection as
of
|
|
|
|
|
|
May 10,
2017
|
|
Production
|
|
|
|
Oil
(MMBbls)
|
4.0 - 4.2
|
|
|
Natural Gas Liquids
(MMBbls)
|
3.0 - 3.2
|
|
|
Total Liquids
(MMBbls)
|
7.0 - 7.4
|
|
|
Natural Gas
(Bcf)
|
42.0 -
43.5
|
|
|
Total
(MMBoe)
|
14.0 -
14.7
|
|
|
|
|
|
|
|
Price
Realization
|
|
|
|
Oil (differential
below NYMEX WTI)
|
$2.75
|
|
|
Natural Gas Liquids
(realized % of NYMEX WTI)
|
26%
|
|
|
Natural Gas
(differential below NYMEX Henry Hub)
|
$1.00
|
|
|
|
|
|
|
|
Costs per
Boe
|
|
|
|
LOE
|
|
$8.00 -
$9.00
|
|
|
Adjusted G&A -
Cash1
|
$4.25 -
$4.50
|
|
|
|
|
|
|
|
% of
Revenue
|
|
|
|
Production
Taxes
|
2.75% -
3.00%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital
Expenditures ($ in millions)
|
Drilling and
Completion
|
|
|
|
Mid-Continent
|
$65 - $70
|
|
|
North Park
Basin
|
20 - 25
|
|
|
Other2
|
24
|
|
Total Drilling and
Completion
|
$109 -
$119
|
|
|
|
|
|
|
|
Other
E&P
|
|
|
|
Land, G&G, and
Seismic
|
$40
|
|
|
Infrastructure3
|
7
|
|
|
Workover
|
37
|
|
|
Capitalized G&A
and Interest
|
15
|
|
Total Other
Exploration and Production
|
$99
|
|
|
|
|
|
|
|
|
General
Corporate
|
2
|
|
Total Capital
Expenditures (excluding acquisitions and plugging and
abandonment)
|
$210 -
$220
|
|
|
|
1)
|
Adjusted
G&A - Cash is a non-GAAP financial measure as it excludes
from G&A non-cash compensation, severance, bad debt allowance,
and other non-recurring items. The most directly comparable GAAP
measure for Adjusted G&A - cash is General and Administrative
Expense. Information to reconcile this non-GAAP financial measure
to the most directly comparable GAAP financial measure is not
available at this time, as management is unable to forecast the
excluded items for future periods.
|
2)
|
2016 Carryover,
Coring, and Non-Op
|
3)
|
Facilities -
Electrical, SWD, Gathering, Pipeline ROW
|
Operational and Financial Statistics
Upon emergence from Chapter 11 reorganization, the Company
elected to adopt fresh start accounting effective October 1, 2016. As a result of the application
of fresh start accounting and the effects of the implementation of
the plan of reorganization, the financial statements on or after
October 1, 2016 will not be
comparable with the financial statements prior to that date.
References to the "Successor" refer to SandRidge subsequent to
adoption of fresh start accounting. References to the "Predecessor"
refer to SandRidge prior to adoption of fresh start accounting.
Information regarding the Company's production, pricing, costs
and earnings is presented below:
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|
|
|
|
|
|
|
|
Successor
|
|
Predecessor
|
|
|
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
Production -
Total
|
|
|
|
|
Oil (MBbl)
|
|
1,134
|
|
1,625
|
NGL (MBbl)
|
|
887
|
|
1,111
|
Natural gas
(MMcf)
|
|
11,766
|
|
16,509
|
Oil equivalent
(MBoe)
|
|
3,982
|
|
5,488
|
Daily production
(MBoed)
|
|
44.2
|
|
60.3
|
|
|
|
|
|
|
|
|
Production -
Mid-Continent
|
|
|
|
|
Oil (MBbl)
|
|
851
|
|
1,430
|
NGL (MBbl)
|
|
872
|
|
1,093
|
Natural gas
(MMcf)
|
|
11,706
|
|
15,856
|
Oil equivalent
(MBoe)
|
|
3,673
|
|
5,166
|
Daily production
(MBoed)
|
|
40.8
|
|
56.8
|
|
|
|
|
|
|
|
|
Average price per
unit
|
|
|
|
|
Realized oil price
per barrel - as reported
|
|
$
49.19
|
|
$
27.95
|
Realized impact of
derivatives per barrel
|
|
0.27
|
|
15.98
|
Net realized price
per barrel
|
|
$
49.46
|
|
$
43.93
|
|
|
|
|
|
|
|
|
Realized NGL price
per barrel - as reported
|
|
$
16.27
|
|
$
10.73
|
Realized impact of
derivatives per barrel
|
|
-
|
|
-
|
Net realized price
per barrel
|
|
$
16.27
|
|
$
10.73
|
|
|
|
|
|
|
|
|
Realized natural gas
price per Mcf - as reported
|
|
$
2.37
|
|
$
1.64
|
Realized impact of
derivatives per Mcf
|
|
(0.08)
|
|
(0.03)
|
Net realized price
per Mcf
|
|
$
2.29
|
|
$
1.61
|
|
|
|
|
|
|
|
|
Realized price per
Boe - as reported
|
|
$
24.65
|
|
$
15.37
|
Net realized price
per Boe - including impact of derivatives
|
|
$
24.49
|
|
$
20.03
|
|
|
|
|
|
|
|
|
Average cost per
Boe
|
|
|
|
|
Lease
operating(1)
|
|
$
6.28
|
|
$
8.62
|
Production
taxes
|
|
0.80
|
|
0.31
|
|
|
|
|
|
|
|
|
General and
administrative
|
|
|
|
|
|
General and
administrative, excluding stock-based compensation
|
|
$
4.19
|
|
$
11.48
|
|
Stock-based
compensation
|
|
0.82
|
|
2.06
|
|
Total general and
administrative
|
|
$
5.01
|
|
$
13.54
|
|
|
|
|
|
|
|
|
General and
administrative - adjusted
|
|
|
|
|
|
General and
administrative, excluding stock-based compensation
(2)
|
|
$
3.43
|
|
$
4.26
|
|
Stock-based
compensation (3)
|
|
0.82
|
|
0.58
|
|
Total general and
administrative - adjusted
|
|
$
4.25
|
|
$
4.84
|
|
|
|
|
|
|
|
|
Depletion
(4)
|
|
$
6.78
|
|
$
6.18
|
|
|
|
|
|
|
|
|
Lease operating
cost per Boe
|
|
|
|
|
Mid-Continent
|
|
$
4.86
|
|
$
7.32
|
|
|
|
|
|
|
|
|
Earnings per
share
|
|
|
|
|
Earnings (loss) per
share applicable to common stockholders
|
|
|
|
|
|
Basic
|
|
$
1.90
|
|
$
(0.47)
|
|
Diluted
|
|
$
1.90
|
|
$
(0.47)
|
|
|
|
|
|
|
|
|
Adjusted net income
per share available to common stockholders
|
|
|
|
|
|
Basic
|
|
$
0.78
|
|
$
(0.14)
|
|
Diluted
|
|
$
0.78
|
|
$
(0.10)
|
|
|
|
|
|
|
|
|
Weighted average
number of shares outstanding (in thousands)
|
|
|
|
|
|
Basic
|
|
26,801
|
|
689,784
|
|
Diluted
(5)
|
|
26,801
|
|
815,750
|
|
|
(1)
|
Transportation costs
are presented as a reduction of revenue by the Successor Company
compared to the Predecessor Company's presentation of these costs
as lease operating expenses.
|
(2)
|
Excludes
restructuring costs and severance totaling $3.0 million for the
three-month period ended March 31, 2017. Excludes doubtful
receivable write-off, severance, restructuring costs and various
other insignificant costs totaling $39.6 million for the
three-month period ended March 31, 2016.
|
(3)
|
Three-month period
ended March 31, 2016 excludes $8.1 million for employee incentive
and retention and the acceleration of certain stock
awards.
|
(4)
|
Includes accretion of
asset retirement obligation.
|
(5)
|
Includes shares
considered antidilutive for calculating earnings per share in
accordance with GAAP for certain periods presented.
|
Capital Expenditures
The table below summarizes the Company's capital expenditures
for the three-month periods ended March 31,
2017 and 2016:
|
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
Predecessor
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
|
|
|
|
(in
thousands)
|
|
|
|
|
|
|
|
|
Drilling and
production
|
|
|
|
|
|
Mid-Continent
|
|
$
19,679
|
|
$
42,086
|
|
Rockies
|
|
4,323
|
|
12,437
|
|
Other
|
|
24
|
|
214
|
|
|
|
|
|
24,026
|
|
54,737
|
Leasehold and
geophysical
|
|
|
|
|
|
Mid-Continent
|
|
11,627
|
|
(6,979)
|
|
Rockies
|
|
3,051
|
|
72
|
|
Other
|
|
323
|
|
1,950
|
|
|
|
|
|
15,001
|
|
(4,957)
|
|
|
|
|
|
|
|
|
Inventory
|
|
(94)
|
|
764
|
|
|
|
|
|
|
|
|
Total exploration and
development
|
|
38,933
|
|
50,544
|
|
|
|
|
|
|
|
|
Other -
operating
|
|
397
|
|
1,230
|
Other -
corporate
|
|
1,402
|
|
1,707
|
|
|
|
|
|
|
|
|
Total capital
expenditures, excluding acquisitions
|
|
40,732
|
|
53,481
|
|
|
|
|
|
|
|
|
Acquisitions
|
|
48,073
|
|
95
|
|
|
|
|
|
|
|
|
Total capital
expenditures
|
|
$
88,805
|
|
$
53,576
|
Capital Expenditures (Guidance Category
Detail)
The table below presents actual results of the Company's capital
expenditures for the three-month period ended March 31, 2017 at the same level of detail as its
full year capital expenditure guidance.
|
|
|
|
|
|
|
|
|
|
|
Three Months
Ended
|
|
|
|
|
|
March 31,
2017
|
|
|
|
|
(in
thousands)
|
|
|
|
|
|
|
Drilling and
Completion
|
|
|
|
Mid-Continent
|
|
$
4,511
|
|
North Park
Basin
|
|
134
|
|
Other1
|
|
10,942
|
Total Drilling and
Completion
|
|
$
15,587
|
|
|
|
Other
E&P
|
|
|
|
Land, G&G, and
Seismic
|
|
$
13,543
|
|
Infrastructure2
|
|
1,142
|
|
Workovers
|
|
6,172
|
|
Capitalized G&A
and Interest
|
|
2,886
|
Total Other
Exploration and Production
|
|
$
23,743
|
|
|
|
|
|
|
General
Corporate
|
|
$
1,402
|
|
|
|
|
|
|
Total Capital
Expenditures (excluding
acquisitions and plugging and abandonment)
|
|
$
40,732
|
|
|
1)
|
2016 Carryover,
Coring, and Non-Op
|
2)
|
Facilities -
Electrical, SWD, Gathering, Pipeline ROW
|
Derivative Contracts
Subsequent to March 31, 2017, the
Company entered into additional gas swap contracts for the calendar
year 2018. The table below sets forth the Company's consolidated
oil and natural gas price swaps for 2017 and 2018 as of
May 10, 2017:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Quarter
Ending
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3/31/2017
|
|
6/30/2017
|
|
9/30/2017
|
|
12/31/2017
|
|
FY
2017
|
Oil
(MMBbls):
|
|
|
|
|
|
|
|
|
|
|
|
|
Swap
Volume
|
|
0.81
|
|
0.82
|
|
0.83
|
|
0.83
|
|
3.29
|
|
Swap
|
|
|
$52.24
|
|
$52.24
|
|
$52.24
|
|
$52.24
|
|
$52.24
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas
(Bcf):
|
|
|
|
|
|
|
|
|
|
|
|
|
Swap
Volume
|
|
8.10
|
|
8.19
|
|
8.28
|
|
8.28
|
|
32.85
|
|
Swap
|
|
|
$3.20
|
|
$3.20
|
|
$3.20
|
|
$3.20
|
|
$3.20
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3/31/2018
|
|
6/30/2018
|
|
9/30/2018
|
|
12/31/2018
|
|
FY
2018
|
Oil
(MMBbls):
|
|
|
|
|
|
|
|
|
|
|
|
|
Swap
Volume
|
|
0.45
|
|
0.46
|
|
0.46
|
|
0.46
|
|
1.83
|
|
Swap
|
|
|
$55.34
|
|
$55.34
|
|
$55.34
|
|
$55.34
|
|
$55.34
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas
(Bcf):
|
|
|
|
|
|
|
|
|
|
|
|
|
Swap
Volume
|
|
4.50
|
|
2.73
|
|
2.76
|
|
2.76
|
|
12.75
|
|
Swap
|
|
|
$3.25
|
|
$3.11
|
|
$3.11
|
|
$3.11
|
|
$3.16
|
Capitalization
The Company's capital structure as of March 31, 2017 and December 31, 2016 is presented below:
|
|
|
|
|
|
|
|
|
|
March
31,
2017
|
|
December
31,
2016
|
|
|
|
|
|
(in
thousands)
|
|
|
|
|
|
|
|
|
Cash, cash
equivalents and restricted cash
|
|
$ 153,839
|
|
$
174,071
|
|
|
|
|
|
|
|
|
|
Credit
facility
|
|
$
-
|
|
$
-
|
|
Building
note
|
|
37,516
|
|
36,528
|
|
Mandatorily
convertible 0% notes
|
|
-
|
|
268,780
|
|
|
|
Total
debt
|
|
37,516
|
|
305,308
|
|
|
|
|
|
|
|
|
Stockholders'
equity
|
|
|
|
|
|
Common
stock
|
|
34
|
|
20
|
|
Warrants
|
|
88,381
|
|
88,381
|
|
Additional paid-in
capital
|
|
1,029,668
|
|
758,498
|
|
Accumulated
deficit
|
|
(283,174)
|
|
(333,982)
|
|
|
Total SandRidge
Energy, Inc. stockholders' equity
|
|
834,909
|
|
512,917
|
|
|
|
|
|
|
|
|
Total
capitalization
|
|
$ 872,425
|
|
$
818,225
|
SandRidge Energy,
Inc. Condensed Consolidated Statements of Operations
(Unaudited)
|
(In thousands,
except per share amounts)
|
|
|
Successor
|
|
Predecessor
|
|
|
|
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
|
|
|
|
Oil, natural gas and
NGL
|
$
98,149
|
|
$
84,375
|
|
Other
|
201
|
|
5,957
|
|
|
Total
revenues
|
98,350
|
|
90,332
|
|
|
|
|
|
Expenses
|
|
|
|
|
|
Production
|
25,023
|
|
47,282
|
|
Production
taxes
|
3,176
|
|
1,708
|
|
Depreciation and
depletion - oil and natural gas
|
24,571
|
|
32,326
|
|
Depreciation and
amortization - other
|
3,837
|
|
6,835
|
|
Accretion of asset
retirement obligations
|
2,409
|
|
1,588
|
|
Impairment
|
2,531
|
|
110,114
|
|
General and
administrative
|
19,938
|
|
74,278
|
|
Gain on derivative
contracts
|
(34,183)
|
|
(2,808)
|
|
Loss on settlement of
contract
|
-
|
|
89,092
|
|
Other operating
expense
|
268
|
|
3,472
|
|
|
Total
expenses
|
47,570
|
|
363,887
|
|
|
Income (loss) from
operations
|
50,780
|
|
(273,555)
|
|
|
|
|
|
|
|
|
|
Other (expense)
income
|
|
|
|
|
Interest
expense
|
(939)
|
|
(81,151)
|
|
Gain on
extinguishment of debt
|
-
|
|
41,331
|
|
Other income,
net
|
970
|
|
153
|
|
|
Total other income
(expense)
|
31
|
|
(39,667)
|
Income (loss) before
income taxes
|
50,811
|
|
(313,222)
|
Income tax
expense
|
3
|
|
4
|
Net income
(loss)
|
50,808
|
|
(313,226)
|
Preferred stock
dividends
|
-
|
|
10,881
|
|
|
Income available
(loss applicable) to SandRidge Energy,
Inc. common
stockholders
|
$
50,808
|
|
$
(324,107)
|
|
|
|
|
|
|
|
|
|
Earnings (loss) per
share
|
|
|
|
|
Basic
|
|
|
$
1.90
|
|
$
(0.47)
|
|
Diluted
|
|
|
$
1.90
|
|
$
(0.47)
|
|
|
|
|
|
|
|
|
|
Weighted average
number of common shares outstanding
|
|
|
|
|
Basic
|
|
|
26,801
|
|
689,784
|
|
Diluted
|
|
|
26,801
|
|
689,784
|
SandRidge Energy,
Inc. Condensed Consolidated Balance Sheets
(Unaudited)
|
(In
thousands)
|
|
|
|
|
|
|
|
|
|
|
March
31,
|
|
December
31,
|
|
2017
|
|
2016
|
|
|
|
|
|
|
|
|
|
ASSETS
|
|
|
|
Current
assets
|
|
|
|
|
Cash and cash
equivalents
|
$
150,998
|
|
$
121,231
|
Restricted cash -
collateral
|
|
-
|
|
50,000
|
Restricted cash -
other
|
|
2,841
|
|
2,840
|
Accounts receivable,
net
|
56,711
|
|
74,097
|
Derivative
contracts
|
1,212
|
|
-
|
Prepaid
expenses
|
|
3,684
|
|
5,375
|
Other current
assets
|
11,952
|
|
3,633
|
|
|
Total current
assets
|
|
227,398
|
|
257,176
|
Oil and natural gas
properties, using full cost method of accounting
|
|
|
|
Proved
|
882,946
|
|
840,201
|
Unproved
|
110,941
|
|
74,937
|
Less:
accumulated depreciation, depletion and impairment
|
(377,280)
|
|
(353,030)
|
|
|
|
|
|
|
616,607
|
|
562,108
|
Other property, plant
and equipment, net
|
|
245,818
|
|
255,824
|
Derivative
contracts
|
|
5,441
|
|
-
|
Other
assets
|
|
1,933
|
|
6,284
|
|
|
Total
assets
|
|
$1,097,197
|
|
$
1,081,392
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND
STOCKHOLDERS' EQUITY
|
|
|
|
Current
liabilities
|
|
|
|
|
Accounts payable and
accrued expenses
|
|
$
105,939
|
|
$
116,517
|
Derivative
contracts
|
1,545
|
|
27,538
|
Asset retirement
obligations
|
67,015
|
|
66,154
|
Other current
liabilities
|
|
7,167
|
|
3,497
|
|
|
Total current
liabilities
|
|
181,666
|
|
213,706
|
Long-term
debt
|
|
37,516
|
|
305,308
|
Derivative
contracts
|
|
-
|
|
2,176
|
Asset retirement
obligations
|
|
41,364
|
|
40,327
|
Other long-term
obligations
|
|
1,742
|
|
6,958
|
|
|
Total
liabilities
|
|
262,288
|
|
568,475
|
Commitments and
contingencies
|
|
|
|
|
Stockholders'
Equity
|
|
|
|
|
Common stock, $0.001
par value; 250,000 shares authorized; 35,855 issued and
outstanding at March 31, 2017 and
21,042 issued and 19,635 outstanding at December 31,
2016
|
34
|
|
20
|
Warrants
|
|
88,381
|
|
88,381
|
Additional paid-in
capital
|
|
1,029,668
|
|
758,498
|
Accumulated
deficit
|
(283,174)
|
|
(333,982)
|
|
|
Total stockholders'
equity
|
|
834,909
|
|
512,917
|
|
|
Total liabilities and
stockholders' equity
|
|
$1,097,197
|
|
$
1,081,392
|
SandRidge Energy,
Inc. Condensed Consolidated Cash Flows (Unaudited)
|
(In
thousands)
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
Predecessor
|
|
|
|
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM
OPERATING ACTIVITIES
|
|
|
|
|
Net income
(loss)
|
$
50,808
|
|
$
(313,226)
|
|
Adjustments to
reconcile net income (loss) to net cash provided by (used in)
operating
activities
|
|
|
|
|
|
Provision for
doubtful accounts
|
|
-
|
|
16,701
|
|
|
Depreciation,
depletion and amortization
|
|
28,408
|
|
39,161
|
|
|
Accretion of asset
retirement obligations
|
|
2,409
|
|
1,588
|
|
|
Impairment
|
|
2,531
|
|
110,114
|
|
|
Debt issuance costs
amortization
|
|
78
|
|
3,350
|
|
|
Amortization of
premiums and discounts on debt
|
(75)
|
|
2,013
|
|
|
Gain on
extinguishment of debt
|
|
-
|
|
(41,331)
|
|
|
Gain on debt
derivatives
|
|
-
|
|
(1,324)
|
|
|
Cash paid for early
conversion of convertible notes
|
-
|
|
(33,452)
|
|
|
Gain on derivative
contracts
|
|
(34,183)
|
|
(2,808)
|
|
|
Cash (paid) received
on settlement of derivative contracts
|
(638)
|
|
25,536
|
|
|
Loss on settlement of
contract
|
|
-
|
|
89,092
|
|
|
Cash paid on
settlement of contract
|
|
-
|
|
(11,000)
|
|
|
Stock-based
compensation
|
|
3,261
|
|
6,753
|
|
|
Other
|
|
360
|
|
(1,791)
|
|
|
Changes in operating
assets and liabilities increasing (decreasing) cash
|
11,277
|
|
(52,020)
|
|
|
|
|
Net cash provided by
(used in) operating activities
|
$
64,236
|
|
(162,644)
|
CASH FLOWS FROM
INVESTING ACTIVITIES
|
|
|
|
|
Capital expenditures
for property, plant and equipment
|
(43,686)
|
|
(70,546)
|
|
Acquisition of
assets
|
|
(48,073)
|
|
(95)
|
|
Proceeds from sale of
assets
|
|
10,203
|
|
3,172
|
|
|
|
|
Net cash used in
investing activities
|
|
(81,556)
|
|
(67,469)
|
CASH FLOWS FROM
FINANCING ACTIVITIES
|
|
|
|
|
Proceeds from
borrowings
|
|
-
|
|
488,900
|
|
Debt issuance
costs
|
|
(1,488)
|
|
(296)
|
|
Purchase of treasury
stock
|
|
(1,424)
|
|
(37)
|
|
|
|
|
Net cash (used in)
provided by financing activities
|
(2,912)
|
|
488,567
|
NET (DECREASE)
INCREASE IN CASH, CASH EQUIVALENTS and RESTRICTED CASH
|
(20,232)
|
|
258,454
|
CASH, CASH
EQUIVALENTS and RESTRICTED CASH, beginning of year
|
174,071
|
|
435,588
|
CASH, CASH
EQUIVALENTS and RESTRICTED CASH, end of period
|
$
153,839
|
|
$
694,042
|
|
|
|
|
|
|
|
|
|
Supplemental
Disclosure of Noncash Investing and Financing Activities
|
|
|
|
|
Cumulative effect of
adoption of ASU 2015-02
|
$
-
|
|
$
(247,566)
|
|
Property, plant and
equipment transferred in settlement of contract
|
$
-
|
|
$
(215,635)
|
|
Change in accrued
capital expenditures
|
$
2,954
|
|
$
17,065
|
|
Equity issued for
debt
|
|
$
(268,779)
|
|
$
(4,409)
|
Non-GAAP Financial Measures
Adjusted operating cash flow, adjusted EBITDA, pro forma
adjusted EBITDA, adjusted net loss, and net debt are non-GAAP
financial measures.
The Company defines adjusted operating cash flow as net cash
provided by (used in) operating activities before changes in
operating assets and liabilities. It defines EBITDA as net income
(loss) before income tax expense, interest expense and
depreciation, depletion and amortization and accretion of asset
retirement obligations. Adjusted EBITDA, as presented herein, is
EBITDA excluding asset impairment, gain on derivative contracts,
cash (paid) received upon settlement of derivative contracts, loss
on settlement of contract, severance, oil field services – exit
costs, gain on extinguishment of debt, restructuring costs and
other various items (including non-cash portion of stock-based
compensation). Pro forma adjusted EBITDA, as presented herein, is
adjusted EBITDA excluding adjusted EBITDA attributable to
properties or subsidiaries sold during the period.
Adjusted operating cash flow and adjusted EBITDA are
supplemental financial measures used by the Company's management
and by securities analysts, investors, lenders, rating agencies and
others who follow the industry as an indicator of the Company's
ability to internally fund exploration and development activities
and to service or incur additional debt. The Company also uses
these measures because adjusted operating cash flow and adjusted
EBITDA relate to the timing of cash receipts and disbursements that
the Company may not control and may not relate to the period in
which the operating activities occurred. Further, adjusted
operating cash flow and adjusted EBITDA allow the Company to
compare its operating performance and return on capital with those
of other companies without regard to financing methods and capital
structure. These measures should not be considered in isolation or
as a substitute for net cash provided by operating activities
prepared in accordance with generally accepted accounting
principles ("GAAP"). Adjusted EBITDA should not be considered as a
substitute for net income, operating income, cash flows from
operating activities or any other measure of financial performance
or liquidity presented in accordance with GAAP. Adjusted EBITDA
excludes some, but not all, items that affect net income and
operating income and these measures may vary among other companies.
Therefore, the Company's adjusted EBITDA may not be comparable to
similarly titled measures used by other companies.
Management also uses the supplemental financial measure of
adjusted net income (loss), which excludes asset impairment, (loss)
gain on derivative contracts, cash (paid) received on settlement of
derivative contracts, loss on settlement of contract, severance,
oil field services – exit costs, gain on extinguishment of debt,
restructuring costs, employee incentive and retention and other
non-cash items from loss applicable to common stockholders.
Management uses this financial measure as an indicator of the
Company's operational trends and performance relative to other oil
and natural gas companies and believes it is more comparable to
earnings estimates provided by securities analysts. Adjusted net
income (loss) is not a measure of financial performance under GAAP
and should not be considered a substitute for loss applicable to
common stockholders.
The Company also uses the term net debt to determine the extent
to which the Company's outstanding debt obligations would be
satisfied by its cash and cash equivalents on hand. Management
believes this metric is useful to investors in determining the
Company's current leverage position following recent significant
events subsequent to the period.
The tables below reconcile the most directly comparable GAAP
financial measures to operating cash flow, EBITDA and adjusted
EBITDA and adjusted net loss.
Reconciliation of
Cash Provided by (Used in) Operating Activities to Adjusted
Operating Cash Flow
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
Predecessor
|
|
|
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
|
|
|
|
|
(in
thousands)
|
Net cash provided by
(used in) operating activities
|
|
$
64,236
|
|
$
(162,644)
|
|
|
|
|
|
|
|
|
|
Changes in operating
assets and liabilities
|
|
(11,277)
|
|
52,020
|
|
|
|
|
|
|
|
|
Adjusted operating
cash flow
|
|
$
52,959
|
|
$
(110,624)
|
Reconciliation of
Net Income (Loss) to EBITDA and Adjusted EBITDA
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
Predecessor
|
|
|
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
|
|
|
|
|
(in
thousands)
|
|
|
|
|
|
|
|
|
Net income
(loss)
|
|
$
50,808
|
|
$
(313,226)
|
|
|
|
|
|
|
|
|
Adjusted
for
|
|
|
|
|
|
Income tax
expense
|
|
3
|
|
4
|
|
Interest
expense
|
|
1,142
|
|
81,727
|
|
Depreciation and
amortization - other
|
|
3,837
|
|
6,835
|
|
Depreciation and
depletion - oil and natural gas
|
|
24,571
|
|
32,326
|
|
Accretion of asset
retirement obligations
|
|
2,409
|
|
1,588
|
EBITDA
|
|
82,770
|
|
(190,746)
|
|
|
|
|
|
|
|
|
|
Asset
impairment
|
|
2,531
|
|
110,114
|
|
Stock-based
compensation
|
|
3,261
|
|
1,700
|
|
Gain on derivative
contracts
|
|
(34,183)
|
|
(2,808)
|
|
Cash (paid) received
upon settlement of derivative contracts
|
|
(638)
|
|
25,536
|
|
Loss on settlement of
contract
|
|
-
|
|
89,092
|
|
Severance
|
|
400
|
|
17,924
|
|
Oil field services -
exit costs
|
|
-
|
|
2,278
|
|
Gain on
extinguishment of debt
|
|
-
|
|
(41,331)
|
|
Restructuring
costs
|
|
2,607
|
|
8,347
|
|
Employee incentive
and retention
|
|
-
|
|
4,530
|
|
Other
|
|
(1,030)
|
|
15,162
|
|
|
|
|
|
|
|
|
Adjusted
EBITDA
|
|
$
55,718
|
|
$
39,798
|
|
|
|
|
|
|
|
|
Less: EBITDA
attributable to WTO properties (2016)
|
|
-
|
|
1,990
|
|
|
|
|
|
|
|
|
Pro forma adjusted
EBITDA
|
|
$
55,718
|
|
$
41,788
|
Reconciliation of
Cash Provided by (Used in) Operating Activities to Adjusted
EBITDA
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
Predecessor
|
|
|
|
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
|
|
|
|
|
|
(in
thousands)
|
|
|
|
|
|
|
|
|
|
Net cash provided by
(used in) operating activities
|
|
$
64,236
|
|
$
(162,644)
|
|
|
|
|
|
|
|
|
|
|
Changes in operating
assets and liabilities
|
|
(11,277)
|
|
52,020
|
|
Interest
expense
|
|
1,142
|
|
81,727
|
|
Cash paid on early
conversion of convertible notes
|
|
-
|
|
33,452
|
|
Cash paid on
settlement of contract
|
|
-
|
|
11,000
|
|
Severance
(1)
|
|
400
|
|
12,870
|
|
Oil field services -
exit costs (1)
|
|
-
|
|
2,278
|
|
Restructuring
costs
|
|
2,607
|
|
8,347
|
|
Employee incentive
and retention
|
|
-
|
|
4,530
|
|
Other
|
|
|
(1,390)
|
|
(3,782)
|
|
|
|
|
|
|
|
|
|
|
Adjusted
EBITDA
|
|
$
55,718
|
|
$
39,798
|
|
|
|
(1)
|
Excludes associated
stock-based compensation.
|
Reconciliation of
Net Income Available (Loss Applicable) to Common Stockholders to
Adjusted Net Income Available (Loss Applicable) to Common
Stockholders
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
Predecessor
|
|
|
|
|
|
|
Three Months
Ended
|
|
Three Months
Ended
|
|
|
|
|
|
|
March 31,
2017
|
|
March 31,
2016
|
|
|
|
|
|
|
(in
thousands)
|
|
|
|
|
|
|
|
|
|
Income available
(loss applicable) to common stockholders
|
|
$
50,808
|
|
$
(324,107)
|
|
|
|
|
|
|
|
|
|
|
Asset
impairment
|
|
2,531
|
|
110,114
|
|
Gain on derivative
contracts
|
|
(34,183)
|
|
(2,808)
|
|
Cash (paid) received
upon settlement of derivative contracts
|
|
(638)
|
|
25,536
|
|
Loss on settlement of
contract
|
|
-
|
|
89,092
|
|
Severance
|
|
400
|
|
17,924
|
|
Oil field services -
exit costs
|
|
-
|
|
2,278
|
|
Gain on
extinguishment of debt
|
|
-
|
|
(41,331)
|
|
Restructuring
costs
|
|
2,607
|
|
8,347
|
|
Employee incentive
and retention
|
|
-
|
|
4,530
|
|
Other
|
|
|
(637)
|
|
14,351
|
|
|
|
|
|
|
|
|
|
|
Adjusted net income
(loss applicable) to common stockholders
|
|
20,888
|
|
(96,074)
|
|
Preferred stock
dividends
|
|
-
|
|
10,881
|
|
Effect of convertible
debt, net of income taxes
|
|
-
|
|
3,912
|
|
|
|
|
|
|
|
|
|
|
Total adjusted net
income (loss)
|
|
$
20,888
|
|
$
(81,281)
|
|
|
|
|
|
|
|
|
|
|
Weighted average
number of common shares outstanding
|
|
|
|
|
|
|
Basic
|
|
26,801
|
|
689,784
|
|
|
Diluted
(1)
|
|
26,801
|
|
815,750
|
|
|
|
|
|
|
|
|
|
|
Total adjusted net
income (loss)
|
|
|
|
|
|
|
Per share -
basic
|
|
$
0.78
|
|
$
(0.14)
|
|
|
Per share -
diluted
|
|
$
0.78
|
|
$
(0.10)
|
|
|
|
(1)
|
Weighted average
fully diluted common shares outstanding for certain periods
presented includes shares that are considered antidilutive for
calculating earnings per share in accordance with GAAP.
|
For further information, please contact:
Duane M. Grubert
EVP – Investor Relations and Strategy
SandRidge Energy, Inc.
123 Robert S. Kerr Avenue
Oklahoma City, OK 73102-6406
(405) 429-5515
Cautionary Note to Investors - 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, including, but not
limited to, the information appearing under the heading
"Operational Guidance." These statements express a belief,
expectation or intention and are generally accompanied by words
that convey projected future events or outcomes. The
forward-looking statements include projections and estimates of the
Company's corporate strategies, future operations, drilling plans,
oil, and natural gas and natural gas liquids production, price
realizations and differentials, hedging program, operating, general
and administrative and other costs, capital expenditures, tax
rates, efficiency and cost reduction initiative outcomes,
infrastructure assessment and investment, and development plans and
appraisal programs. We have based these forward-looking statements
on our current expectations and assumptions and analyses made by us
in light of our experience and our perception of historical trends,
current conditions and expected future developments, as well as
other factors we believe are appropriate under the circumstances.
However, whether actual results and developments will conform with
our expectations and predictions is subject to a number of risks
and uncertainties, including the volatility of oil and natural gas
prices, our success in discovering, estimating, developing and
replacing oil and natural gas reserves, actual decline curves and
the actual effect of adding compression to natural gas wells, the
availability and terms of capital, the ability of counterparties to
transactions with us to meet their obligations, our timely
execution of hedge transactions, credit conditions of global
capital markets, changes in economic conditions, the amount and
timing of future development costs, the availability and demand for
alternative energy sources, regulatory changes, including those
related to carbon dioxide and greenhouse gas emissions, and other
factors, many of which are beyond our control. We refer you to the
discussion of risk factors in Part I, Item 1A - "Risk Factors" of
our Annual Report on Form 10-K for the year ended December 31, 2016 and in comparable "Risk Factor"
sections of our Quarterly Reports on Form 10-Q filed after such
form 10-K. All of the forward-looking statements made in this press
release are qualified by these cautionary statements. The actual
results or developments anticipated may not be realized or, even if
substantially realized, they may not have the expected consequences
to or effects on our Company or our business or operations. Such
statements are not guarantees of future performance and actual
results or developments may differ materially from those projected
in the forward-looking statements. We undertake no obligation to
update or revise any forward-looking statements.
SandRidge Energy, Inc. (NYSE: SD) is an oil and natural gas
exploration and production company headquartered in Oklahoma City, Oklahoma with its principal
focus on developing high-return, growth-oriented projects in the
U.S. Mid-Continent and Niobrara Shale.
To view the original version on PR Newswire,
visit:http://www.prnewswire.com/news-releases/sandridge-energy-inc-reports-financial-and-operational-results-for-first-quarter-of-2017-300455439.html
SOURCE SandRidge Energy, Inc.