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Midstates Petroleum Announces Third Quarter 2018 Results; Reports Net Income of $11.5 Million, $0.44 Per Share TULSA, Okla.
Midstates Petroleum Company, Inc. (“Midstates” or the “Company”) (NYSE:
MPO) today announced its third quarter 2018 operational and financial
results.
Third Quarter 2018 Highlights and Recent Key
Items
-
Continued execution of its market-focused strategy aimed at reducing
costs, generating substantial free cash flow, improving liquidity and
focusing activity to maximize optionality
-
Reported net income of $11.5 million, or $0.44 per share, which
includes the impact of a $6.6 million loss on commodity derivative
contracts
-
Grew Mississippian Lime production to 17,996 barrels of oil equivalent
per day (BOEPD) in the third quarter of 2018, a 5% increase from
17,202 BOEPD in the second quarter of 2018 and a 16% increase from
15,518 BOEPD in the first quarter of 2018
-
Generated Adjusted EBITDA of $31.9 million, excluding costs incurred
for strategic reviews, outpacing operational capital expenditures by
approximately $10.4 million
-
Reduced full-year 2018 operational CAPEX guidance by approximately 10%
while maintaining the mid-point of yearly production guidance of
17,000 BOEPD
-
Reaffirmed the Company’s borrowing base at $170 million
-
Announced changes to Midstates’ Board of Directors
-
Reiterated a near-term intent to return capital to shareholders
potentially through a share repurchase program(1) and/or
cash dividends(1) which are being reviewed by Management
and the Board
For the third quarter of 2018, Midstates reported net income of $11.5
million, or $0.44 per share, which included the impact of a $6.6 million
charge related to the Company’s commodity derivative contracts. In the
same period in 2017, the Company reported net income of $3.7 million, or
$0.14 per share, including the impact of a $3.6 million commodity
derivative charge, and in the second quarter of 2018 reported a net loss
of $1.5 million, or ($0.06) per share, including the impact of a $7.8
million commodity derivative charge. In the third quarter of 2018,
Midstates generated Adjusted EBITDA of $31.9 million, excluding advisory
fees and costs incurred for strategic reviews. This compares to $30.2
million for the same quarter in 2017 and $27.0 million for the second
quarter of 2018.
David Sambrooks, President and Chief Executive Officer, commented, “We
are very pleased with our continued strong quarterly results, which have
allowed Midstates to achieve several notable accomplishments this year.
Thus far in 2018, we have generated $88.6 million in Adjusted EBITDA,
sold our non-core Anadarko asset and paid down $100 million in debt. We
have made strides operationally to optimize base production through a
substantial workover program, drive down lease operating and overhead
expenses, and grow production from our valuable Miss Lime asset. We have
drilled and completed several two mile lateral wells in the Miss Lime
and we are taking a pause in our fourth quarter drilling activity to
better incorporate the learnings from our drilling and completion
successes into our ongoing program. We believe that two mile laterals
are proving to be more economic and want to ensure that we plan our
future development program to maximize the number of extended laterals
that we can drill.”
Mr. Sambrooks continued, “We are forecasting significant free cash flow
generation moving forward and are investigating ways to return a
substantial portion of this excess cash to our shareholders through a
possible share repurchase program or cash dividends. We continue to
believe in the significant value of our Miss Lime asset and we will use
our strong financial position and clean balance sheet to actively pursue
all opportunities that further us financially and operationally. Our
Management team and our Board, including its newly appointed members,
are focused on creating value for our shareholders and are energized
about Midstates’ future.”
(1) Subject to availability under then current credit agreement
(Adjusted EBITDA, Adjusted Cash Operating Expenses, and Adjusted Cash
General and Administrative Expenses are non-GAAP financial measures.
Each measure is defined and reconciled to the most directly comparable
GAAP measure under “Non-GAAP Financial Measures” in the tables below.)
Operational Update
Key Highlights:
-
Grew Mississippian Lime production to 17,996 BOEPD in the third
quarter of 2018, an increase of about 5% from 17,202 BOEPD in the
second quarter of 2018 and a 16% increase from 15,518 BOEPD in the
first quarter of 2018
-
Production of 17,996 BOEPD in the third quarter of 2018 consisted
of 29% oil, 24% natural gas liquids (NGLs), and 47% natural gas
-
Spud three wells (including two extended lateral wells) and placed
eight wells online (including two extended lateral wells) during the
third quarter of 2018
The Company continued to run its one-rig drilling program in the
Mississippian Lime through the third quarter of 2018 with the goal of
minimizing drilling and completion costs to enhance economics in
delineated areas with extended lateral wells. The Company has drilled
and completed four extended lateral wells in 2018.
At the end of the third quarter of 2018, Midstates’ rig contractor
approached the Company with an option to farm-out the drilling rig to
another operator for a multiple well package starting early in the
fourth quarter of 2018. In order to further study the production results
of its recent extended lateral wells, Midstates elected to farm-out the
rig for a portion of the fourth quarter of 2018.
The Company did not bring online any new saltwater disposal injection
wells during the third quarter of 2018. Midstates is currently operating
11 non-Arbuckle injection wells in Woods and Alfalfa Counties, Oklahoma,
with permitted injection capacity of approximately 240,000 barrels of
water per day. The Company’s total permitted injection capacity in all
formations in Woods and Alfalfa Counties, Oklahoma, which may differ
from actual injection capacity due to operational constraints, is
approximately 372,000 barrels of water per day. The Company’s current
disposal rate into all formations of approximately 160,000 barrels of
water per day. Approximately 45% of the Company’s water injection is
currently being injected into non-Arbuckle formations.
Production and Pricing
Production during the third quarter of 2018 totaled 17,996 BOEPD,
compared with 17,202 BOEPD during the second quarter of 2018, which
excludes 3,382 BOEPD attributable to the Company’s Anadarko Basin
producing properties that were divested during the second quarter of
2018. Oil volumes comprised 29% of total production, NGLs 24%, and
natural gas 47% during the third quarter of 2018.
On January 1, 2018, Midstates adopted Accounting Standards Codification
606, Revenue from Contracts with Customers (“ASC 606”). As a
result, gathering and transportation and a portion of lease operating
expenses are now being presented net against oil, NGLs and natural gas
revenues.
Total oil, NGLs and natural gas revenues in the third quarter of 2018
were approximately $53.0 million, before the impact of derivatives and
including $3.1 million of gathering and transportation expense. In the
second quarter of 2018, oil, NGLs and natural gas revenues, excluding
revenues from the Company’s Anadarko Basin producing properties that
were divested during the second quarter, totaled $46.5 million, which
included $3.4 million of gathering and transportation expense. The net
loss on derivatives for the third quarter of 2018 was $6.6 million,
compared with an $11.3 million loss during the second quarter of 2018.
The following table sets forth information regarding average realized
sales prices for the periods indicated:
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Crude Oil
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NGLs
|
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Natural Gas
|
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|
|
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Three Months
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Three Months
|
|
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Three Months
|
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Three Months
|
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Three Months
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Three Months
|
|
|
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Ended
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|
Ended
|
|
|
Ended
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|
Ended
|
|
|
Ended
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Ended
|
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September 30,
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June 30,
|
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September 30,
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June 30,
|
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September 30,
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June 30,
|
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|
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2018
|
|
|
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2018
|
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|
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2018
|
|
|
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2018
|
|
|
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2018
|
|
|
|
|
2018
|
|
|
Average sales price exclusive of realized derivatives and certain
deductions from revenue
|
|
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$
|
68.83
|
|
|
|
$
|
67.42
|
|
|
|
$
|
32.51
|
|
|
|
$
|
28.28
|
|
|
|
$
|
2.17
|
|
|
|
$
|
2.01
|
|
|
Realized derivatives
|
|
|
|
(8.11
|
)
|
|
|
|
(7.44
|
)
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
0.02
|
|
|
|
|
0.05
|
|
|
Average sales price with realized derivatives exclusive of certain
deductions from revenue
|
|
|
$
|
60.72
|
|
|
|
$
|
59.98
|
|
|
|
$
|
32.51
|
|
|
|
$
|
28.28
|
|
|
|
$
|
2.19
|
|
|
|
$
|
2.06
|
|
|
Certain deductions from revenue
|
|
|
|
(0.04
|
)
|
|
|
|
(0.03
|
)
|
|
|
|
(0.03
|
)
|
|
|
|
(0.04
|
)
|
|
|
|
(0.68
|
)
|
|
|
|
(0.67
|
)
|
|
Average sales price inclusive of realized derivatives and certain
deductions from revenue
|
|
|
$
|
60.68
|
|
|
|
$
|
59.95
|
|
|
|
$
|
32.48
|
|
|
|
$
|
$28.24
|
|
|
|
$
|
1.51
|
|
|
|
$
|
1.39
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
|
|
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|
|
|
|
|
|
|
|
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|
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|
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|
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|
|
|
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Hedging Update
To reduce downside commodity price risk and protect cash flow, Midstates
has entered into a number of swaps and three-way collars to hedge a
portion of the Company’s oil and natural gas revenues through 2020. A
summary of the Company’s hedges is included in the below table.
|
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NYMEX WTI
|
|
|
|
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Fixed Swaps
|
|
|
Three-Way Collars
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
Weighted
|
|
|
|
|
Hedge
|
|
|
Avg
|
|
|
Hedge
|
|
|
Avg
|
|
|
Weighted
|
|
|
Avg
|
|
|
|
|
Position
|
|
|
Strike
|
|
|
Position
|
|
|
Ceiling
|
|
|
Avg Floor
|
|
|
Sub-Floor
|
|
|
|
|
(Bbls)
|
|
|
Price
|
|
|
(Bbls)
|
|
|
Price
|
|
|
Price
|
|
|
Price
|
|
Quarter Ended:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2018(2)
|
|
|
175,720
|
|
|
$
|
57.23
|
|
|
184,000
|
|
|
$
|
59.93
|
|
|
$
|
50.00
|
|
|
$
|
40.00
|
|
December 31, 2018(2)
|
|
|
313,720
|
|
|
$
|
58.59
|
|
|
46,000
|
|
|
$
|
56.70
|
|
|
$
|
50.00
|
|
|
$
|
40.00
|
|
March 31, 2019(2)
|
|
|
171,000
|
|
|
$
|
66.48
|
|
|
180,000
|
|
|
$
|
63.14
|
|
|
$
|
53.75
|
|
|
$
|
43.75
|
|
June 30, 2019(2)
|
|
|
133,900
|
|
|
$
|
64.86
|
|
|
182,000
|
|
|
$
|
63.14
|
|
|
$
|
53.75
|
|
|
$
|
43.75
|
|
September 30, 2019(2)
|
|
|
46,000
|
|
|
$
|
62.96
|
|
|
184,000
|
|
|
$
|
63.14
|
|
|
$
|
53.75
|
|
|
$
|
43.75
|
|
December 31, 2019(2)
|
|
|
46,000
|
|
|
$
|
61.43
|
|
|
184,000
|
|
|
$
|
63.14
|
|
|
$
|
53.75
|
|
|
$
|
43.75
|
|
March 31, 2020(2)
|
|
|
—
|
|
|
$
|
—
|
|
|
91,000
|
|
|
$
|
65.75
|
|
|
$
|
50.00
|
|
|
$
|
40.00
|
|
June 30, 2020(2)
|
|
|
—
|
|
|
$
|
—
|
|
|
91,000
|
|
|
$
|
65.75
|
|
|
$
|
50.00
|
|
|
$
|
40.00
|
|
September 30, 2020(2)
|
|
|
—
|
|
|
$
|
—
|
|
|
92,000
|
|
|
$
|
65.75
|
|
|
$
|
50.00
|
|
|
$
|
40.00
|
|
December 31, 2020(2)
|
|
|
—
|
|
|
$
|
—
|
|
|
92,000
|
|
|
$
|
65.75
|
|
|
$
|
50.00
|
|
|
$
|
40.00
|
|
|
|
|
|
|
|
|
|
NYMEX HENRY HUB
|
|
|
|
|
Fixed Swaps
|
|
|
Three-Way Collars
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
Weighted
|
|
|
Weighted
|
|
|
|
|
Hedge
|
|
|
Weighted
|
|
|
Hedge
|
|
|
Avg
|
|
|
Avg
|
|
|
Avg
|
|
|
|
|
Position
|
|
|
Avg Strike
|
|
|
Position
|
|
|
Ceiling
|
|
|
Floor
|
|
|
Sub-Floor
|
|
|
|
|
(MMBtu)
|
|
|
Price
|
|
|
(MMBtu)
|
|
|
Price
|
|
|
Price
|
|
|
Price
|
|
Quarter Ended:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2018(2)
|
|
|
2,116,000
|
|
|
$
|
2.84
|
|
|
1,380,000
|
|
|
$
|
3.40
|
|
|
$
|
3.00
|
|
|
$
|
2.50
|
|
December 31, 2018(2)
|
|
|
2,055,000
|
|
|
$
|
2.95
|
|
|
1,380,000
|
|
|
$
|
3.40
|
|
|
$
|
3.00
|
|
|
$
|
2.50
|
|
March 31, 2019(2)
|
|
|
1,980,000
|
|
|
$
|
3.01
|
|
|
1,350,000
|
|
|
$
|
3.40
|
|
|
$
|
3.00
|
|
|
$
|
2.50
|
|
_______________________
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|
(2) Positions shown represent open commodity derivative contract
positions as of September 30, 2018.
|
|
|
Costs and Expenses
Adjusted Cash Operating Expenses (which excludes debt restructuring and
advisory fees, as well as severance costs) for the third quarter of 2018
were $18.6 million, or $11.21 per barrel of oil equivalent (Boe),
compared with $23.1 million, or $13.05 per Boe, in the second quarter of
2018. The decrease in adjusted cash operating expenses for the third
quarter of 2018 was due primarily to lower workover expenses.
Lease operating expenses (LOE) and workover expenses combined totaled
$11.9 million, or $7.16 per Boe, in the third quarter of 2018, compared
with $17.0 million, or $9.57 per Boe, in the second quarter of 2018. LOE
per Boe decreased by $0.64, during the third quarter of 2018 compared to
the second quarter of 2018 primarily due to the sale of the Company’s
Anadarko Basin producing properties, which had higher LOE per Boe. Third
quarter 2018 workover expenses decreased $1.77 per BOE from the second
quarter of 2018 due to the Company’s completion of its expanded workover
program.
Severance and other taxes for the third quarter of 2018 were $3.4
million, or $2.03 per Boe (6.2% of oil, NGLs and natural gas sales
revenue), compared to $2.8 million, or $1.57 per Boe (5.2% of oil, NGLs
and natural gas sales revenue) in the second quarter of 2018. Severance
and other tax rates have increased from prior quarters due to
legislation that was signed into law in Oklahoma that increased the 4%
incentive tax rate to 7% effective with December 2017 production.
Additionally, new legislation was signed into law in March 2018 in
Oklahoma to further amend the gross production incentive tax rate for
wells drilled beginning July 1, 2015 from 2.0% to 5.0% effective July
2018.
General and administrative expenses for the third quarter of 2018
totaled $4.7 million, or $2.84 per Boe, compared to $5.2 million, or
$2.93 per Boe, in the second quarter of 2018. General and administrative
expenses decreased in the third quarter of 2018 due to lower employee
costs. Third quarter 2018 and second quarter 2018 general and
administrative expenses included net non-cash, share-based compensation
expense of $0.9 million, or $0.55 per Boe, and $1.2 million, or $0.69
per Boe, respectively. Adjusted cash general and administrative
expenses, which excludes non-cash share-based compensation and certain
non-recurring items, but includes capitalized general and administrative
costs, totaled $3.9 million, or $2.33 per Boe for the third quarter of
2018, compared to $4.0 million, or $2.24 per Boe, in the second quarter
of 2018. Third quarter 2018 adjusted cash general and administrative
expenses increased on a per Boe basis compared to second quarter of 2018
due to lower production that resulted from Company’s Anadarko Basin
producing properties divestiture.
Depreciation, depletion and amortization expense for the third quarter
of 2018 totaled $15.5 million, or $9.36 per Boe, compared to $16.5
million, or $9.30 per Boe in the second quarter of 2018.
Interest expense totaled $0.7 million (net of amounts capitalized) for
the third quarter of 2018, compared to $1.3 million in the second
quarter of 2018. The Company capitalized $0.1 million in interest to
unproved properties in both the third quarter and second quarter of 2018.
The Company had an effective tax rate of 0% and did not record an income
tax expense or benefit for both the third quarter of 2018 and the second
quarter of 2018.
Capital Expenditures
In the third quarter of 2018, the Company invested $21.5 million of
operating capital in the Mississippian Lime assets.
The following table provides operational capital spending by area as
well as a reconciliation to total capital expenditures for the three
months and nine months ended September 30, 2018 (in thousands):
|
|
|
|
For the Three
|
|
|
For the Nine
|
|
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
|
|
September 30, 2018
|
|
|
September 30, 2018
|
|
Drilling and completion activities
|
|
|
$
|
20,179
|
|
|
|
$
|
87,584
|
|
|
Acquisition of acreage and seismic data
|
|
|
|
1,327
|
|
|
|
|
5,279
|
|
|
Operational capital expenditures incurred
|
|
|
$
|
21,506
|
|
|
|
$
|
92,863
|
|
|
Capitalized G&A, office, ARO & other
|
|
|
|
1,160
|
|
|
|
|
3,349
|
|
|
Capitalized interest
|
|
|
|
122
|
|
|
|
|
313
|
|
|
Total capital expenditures incurred
|
|
|
$
|
22,788
|
|
|
|
$
|
96,525
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three
|
|
|
For the Nine
|
|
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
|
|
September 30, 2018
|
|
|
September 30, 2018
|
|
Mississippian Lime
|
|
|
$
|
21,531
|
|
|
|
$
|
92,927
|
|
|
Anadarko Basin
|
|
|
|
(25
|
)
|
|
|
|
(64
|
)
|
|
Total operational capital expenditures incurred
|
|
|
$
|
21,506
|
|
|
|
$
|
92,863
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance Sheet and Liquidity
On September 30, 2018, the Company’s liquidity was approximately $146.2
million, consisting of cash and cash equivalents of $6.2 million and
$140.0 million available under its reserve-based revolving credit
facility. Midstates’ long-term debt was $28.1 million, resulting in net
debt of approximately $21.9 million.
As of September 30, 2018, the Company made $100 million in pay-downs
during 2018 to the outstanding credit facility balance with proceeds
from the sale of the Anadarko Basin producing properties and cash on
hand. These pay-downs will reduce annualized interest expense by
approximately $6 million.
On October 24, 2018, the Company’s borrowing base under its revolving
credit facility was reaffirmed at $170 million. The next scheduled
borrowing base redetermination will occur during the second quarter of
2019.
Updated Full-Year 2018 Guidance
|
|
|
|
|
|
|
Production Guidance (Boe/d)
|
|
|
|
16,750 – 17,250
|
|
|
|
|
|
|
|
Operational CAPEX Guidance
|
|
|
|
$95 million - $100 million
|
|
|
|
|
|
|
|
Price Differential Guidance
|
|
Oil (per Bbl)
|
|
|
|
$0.70
|
|
NGLs (realized % of WTI)
|
|
|
|
44%
|
|
Natural Gas inclusive of G&T(1) (per MMBTU)
|
|
|
|
$1.35
|
|
Cost Guidance per Boe
|
|
Lease Operating Expenses
|
|
|
|
$5.50 - $5.70
|
|
Expense Workover
|
|
|
|
$1.90 - $2.10
|
|
Severance & Other Taxes
|
|
|
|
$1.55 - $1.75
|
|
Adjusted G&A – Cash(2)
|
|
|
|
$2.50 - $2.70
|
|
(1)
|
|
Inclusive of Gathering & Transportation expenses that were
previously represented separately under “Cost Guidance per BOE” at
$1.75 - $2.25 per Boe
|
|
(2)
|
|
Adjusted G&A – Cash is a non-GAAP financial measure as it excludes
from G&A non-cash compensation and other non-recurring items, but
includes capitalized general and administrative costs.
|
|
|
|
|
Board of Director Changes
The Company also announced yesterday changes to its Board of Directors.
Midstates’ Board named Randal Klein, Evan Lederman, and David Proman to
the Board effective upon the resignation of Frederic (Jake) F. Brace,
Michael Reddin, and Bruce Vincent on November 7, 2018. The firms they
represent collectively own approximately 40% of Midstates’ outstanding
shares. The new Board expects to focus on returning a significant amount
of capital to shareholders from anticipated free cash flow generation of
the Company while also pursuing strategic and opportunistic mergers and
acquisitions. Several options are being reviewed by the Board and
management to return capital to shareholders including a share
repurchase program(1) and/or issue cash dividends(1).
(1) Subject to availability under then current credit agreement
Conference Call Information
The Company will host a conference call to discuss third quarter 2018
results on Friday, November 9, at 9:00 a.m. Eastern time (8:00 a.m.
Central time). Participants may join the conference call by dialing
(877) 645-4610 (for U.S. and Canada) or (707) 595-2723 (International).
The conference call access code is 3185546 for all participants. To
listen via live web cast, please visit the Investor Relations section of
the Company’s website, www.midstatespetroleum.com.
An audio replay of the conference call will be available approximately
two hours after the conclusion of the call. The audio replay will remain
available for approximately 30 days and can be accessed by dialing (855)
859-2056 (for U.S. and Canada) or (404) 537-3406 (International). The
conference call audio replay access code is 3185546 for all
participants. The audio replay will also be available in the Investors
section of the Company’s website approximately two hours after the
conclusion of the call and remain available for approximately 30 days.
Forward-Looking Statements
This press release contains forward-looking statements within the
meaning of Section 27A of the Securities Act of 1933 and Section 21E of
the Securities Exchange Act of 1934. All statements that are not
statements of historical fact, including statements regarding the
Company’s strategy, future operations, financial position, estimated
revenues and losses, projected costs, resource potential, drilling
locations, prospects and plans and objectives of management, are
considered forward-looking statements. Without limiting the generality
of the foregoing, these statements are based on certain assumptions made
by the Company based on management's experience, expectations and
perception of historical trends, current conditions, anticipated future
developments and other factors believed to be appropriate. Although the
Company believes that its plans, intentions and expectations reflected
in or suggested by the forward-looking statements made in this press
release are reasonable, the Company gives no assurance that these plans,
intentions or expectations will be achieved when anticipated or at all.
Moreover, such statements are subject to a number of factors, many of
which are beyond the control of the Company, which may cause actual
results to differ materially from those implied or expressed by the
forward-looking statements. These factors include, but are not limited
to variations in the market demand for, and prices of, oil and natural
gas; uncertainties about the Company’s estimated quantities of oil and
natural gas reserves, resource potential and drilling locations; the
adequacy of the Company’s capital resources and liquidity; general
economic and business conditions; weather-related downtime; failure to
realize expected value creation from property acquisitions;
uncertainties about the Company’s ability to replace reserves and
economically develop its current reserves; risks related to the
concentration of the Company’s operations; drilling results; and
potential financial losses or earnings reductions from the Company’s
commodity derivative positions.
Any forward-looking statement speaks only as of the date on which such
statement is made and the Company undertakes no obligation to correct or
update any forward-looking statement, whether as a result of new
information, future events or otherwise, except as required by
applicable law.
About Midstates Petroleum Company, Inc.
Midstates Petroleum Company, Inc. is an independent exploration and
production company focused on the application of modern drilling and
completion techniques in oil and liquids-rich basins in the onshore U.S.
The Company’s operations are currently focused on oilfields in the
Mississippian Lime play in Oklahoma.
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
CONSOLIDATED BALANCE SHEETS
|
|
|
|
(In thousands, except share amounts)
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
September 30, 2018
|
|
|
June 30, 2018
|
|
|
December 31, 2017
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
CURRENT ASSETS:
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
|
$
|
6,213
|
|
|
|
$
|
6,256
|
|
|
|
$
|
68,498
|
|
|
Accounts receivable:
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales
|
|
|
|
29,472
|
|
|
|
|
30,278
|
|
|
|
|
32,455
|
|
|
Joint interest billing
|
|
|
|
3,178
|
|
|
|
|
4,598
|
|
|
|
|
3,297
|
|
|
Other
|
|
|
|
449
|
|
|
|
|
298
|
|
|
|
|
166
|
|
|
Commodity derivative contracts
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
762
|
|
|
Other current assets
|
|
|
|
1,813
|
|
|
|
|
2,474
|
|
|
|
|
1,510
|
|
|
Total current assets
|
|
|
|
41,125
|
|
|
|
|
43,904
|
|
|
|
|
106,688
|
|
|
PROPERTY AND EQUIPMENT:
|
|
|
|
|
|
|
|
|
|
|
Oil and gas properties, on the basis of full-cost accounting
|
|
|
|
|
|
|
|
|
|
|
Proved properties
|
|
|
|
803,841
|
|
|
|
|
778,741
|
|
|
|
|
765,308
|
|
|
Unproved properties not being amortized
|
|
|
|
4,505
|
|
|
|
|
4,383
|
|
|
|
|
7,065
|
|
|
Other property and equipment
|
|
|
|
6,369
|
|
|
|
|
6,243
|
|
|
|
|
6,508
|
|
|
Less accumulated depreciation, depletion and amortization
|
|
|
|
(251,432
|
)
|
|
|
|
(235,948
|
)
|
|
|
|
(204,419
|
)
|
|
Net property and equipment
|
|
|
|
563,283
|
|
|
|
|
553,419
|
|
|
|
|
574,462
|
|
|
OTHER NONCURRENT ASSETS
|
|
|
|
5,591
|
|
|
|
|
5,263
|
|
|
|
|
6,978
|
|
|
TOTAL
|
|
|
$
|
609,999
|
|
|
|
$
|
602,586
|
|
|
|
$
|
688,128
|
|
|
LIABILITIES AND EQUITY
|
|
|
|
|
|
|
|
|
|
|
CURRENT LIABILITIES:
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
|
$
|
14,322
|
|
|
|
$
|
19,216
|
|
|
|
$
|
11,547
|
|
|
Accrued liabilities
|
|
|
|
36,703
|
|
|
|
|
40,327
|
|
|
|
|
42,842
|
|
|
Commodity derivative contracts
|
|
|
|
13,210
|
|
|
|
|
11,549
|
|
|
|
|
3,433
|
|
|
Total current liabilities
|
|
|
|
64,235
|
|
|
|
|
71,092
|
|
|
|
|
57,822
|
|
|
LONG-TERM LIABILITIES:
|
|
|
|
|
|
|
|
|
|
|
Asset retirement obligations
|
|
|
|
7,816
|
|
|
|
|
7,573
|
|
|
|
|
15,506
|
|
|
Commodity derivative contracts
|
|
|
|
4,361
|
|
|
|
|
3,293
|
|
|
|
|
562
|
|
|
Long-term debt
|
|
|
|
28,059
|
|
|
|
|
28,059
|
|
|
|
|
128,059
|
|
|
Other long-term liabilities
|
|
|
|
569
|
|
|
|
|
578
|
|
|
|
|
592
|
|
|
Total long-term liabilities
|
|
|
|
40,805
|
|
|
|
|
39,503
|
|
|
|
|
144,719
|
|
|
|
|
|
|
|
|
|
|
|
|
|
COMMITMENTS AND CONTINGENCIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
STOCKHOLDERS’ EQUITY:
|
|
|
|
|
|
|
|
|
|
|
Preferred stock, $0.01 par value, 50,000,000 shares authorized
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
—
|
|
|
Warrants, 6,625,554 warrants outstanding
|
|
|
|
37,329
|
|
|
|
|
37,329
|
|
|
|
|
37,329
|
|
|
Common stock, $0.01 par value, 250,000,000 shares authorized
|
|
|
|
254
|
|
|
|
|
254
|
|
|
|
|
253
|
|
|
Treasury stock
|
|
|
|
(2,081
|
)
|
|
|
|
(2,081
|
)
|
|
|
|
(1,603
|
)
|
|
Additional paid-in-capital
|
|
|
|
530,627
|
|
|
|
|
529,175
|
|
|
|
|
524,755
|
|
|
Retained deficit
|
|
|
|
(61,170
|
)
|
|
|
|
(72,686
|
)
|
|
|
|
(75,147
|
)
|
|
Total stockholders’ equity
|
|
|
|
504,959
|
|
|
|
|
491,991
|
|
|
|
|
485,587
|
|
|
TOTAL
|
|
|
$
|
609,999
|
|
|
|
$
|
602,586
|
|
|
|
$
|
688,128
|
|
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
CONSOLIDATED STATEMENTS OF OPERATIONS
|
|
|
|
(In thousands)
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
For the Three
|
|
|
For the Three
|
|
|
For the Three
|
|
|
For the Nine
|
|
|
For the Nine
|
|
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
|
|
September 30,
|
|
|
June 30,
|
|
|
September 30,
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
|
2018
|
|
|
2018
|
|
|
2017
|
|
|
2018
|
|
|
2017
|
|
REVENUES:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil sales
|
|
|
$
|
33,218
|
|
|
|
$
|
34,202
|
|
|
|
$
|
27,190
|
|
|
|
$
|
99,834
|
|
|
|
$
|
85,497
|
|
|
Natural gas liquid sales
|
|
|
|
12,720
|
|
|
|
|
11,893
|
|
|
|
|
10,656
|
|
|
|
|
35,651
|
|
|
|
|
31,580
|
|
|
Natural gas sales
|
|
|
|
7,026
|
|
|
|
|
6,782
|
|
|
|
|
13,970
|
|
|
|
|
22,145
|
|
|
|
|
46,321
|
|
|
Other revenue
|
|
|
|
1,384
|
|
|
|
|
795
|
|
|
|
|
1,490
|
|
|
|
|
3,234
|
|
|
|
|
3,244
|
|
|
Total revenues from contracts with customers
|
|
|
|
54,348
|
|
|
|
|
53,672
|
|
|
|
|
53,306
|
|
|
|
|
160,864
|
|
|
|
|
166,642
|
|
|
Gains (losses) on commodity derivative contracts—net
|
|
|
|
(6,583
|
)
|
|
|
|
(11,348
|
)
|
|
|
|
(3,591
|
)
|
|
|
|
(21,870
|
)
|
|
|
|
8,767
|
|
|
Total revenues
|
|
|
|
47,765
|
|
|
|
|
42,324
|
|
|
|
|
49,715
|
|
|
|
|
138,994
|
|
|
|
|
175,409
|
|
|
EXPENSES:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating and workover
|
|
|
|
11,861
|
|
|
|
|
16,952
|
|
|
|
|
15,653
|
|
|
|
|
43,621
|
|
|
|
|
48,064
|
|
|
Gathering and transportation
|
|
|
|
54
|
|
|
|
|
67
|
|
|
|
|
3,699
|
|
|
|
|
178
|
|
|
|
|
11,027
|
|
|
Severance and other taxes
|
|
|
|
3,360
|
|
|
|
|
2,776
|
|
|
|
|
2,352
|
|
|
|
|
8,998
|
|
|
|
|
6,168
|
|
|
Asset retirement accretion
|
|
|
|
147
|
|
|
|
|
250
|
|
|
|
|
274
|
|
|
|
|
694
|
|
|
|
|
833
|
|
|
Depreciation, depletion, and amortization
|
|
|
|
15,485
|
|
|
|
|
16,484
|
|
|
|
|
15,170
|
|
|
|
|
47,182
|
|
|
|
|
46,471
|
|
|
General and administrative
|
|
|
|
4,688
|
|
|
|
|
5,190
|
|
|
|
|
7,255
|
|
|
|
|
19,735
|
|
|
|
|
23,102
|
|
|
Advisory fees
|
|
|
|
—
|
|
|
|
|
850
|
|
|
|
|
—
|
|
|
|
|
850
|
|
|
|
|
—
|
|
|
Total expenses
|
|
|
|
35,595
|
|
|
|
|
42,569
|
|
|
|
|
44,403
|
|
|
|
|
121,258
|
|
|
|
|
135,665
|
|
|
OPERATING INCOME (LOSS)
|
|
|
|
12,170
|
|
|
|
|
(245
|
)
|
|
|
|
5,312
|
|
|
|
|
17,736
|
|
|
|
|
39,744
|
|
|
OTHER EXPENSE:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
|
4
|
|
|
|
|
5
|
|
|
|
|
—
|
|
|
|
|
28
|
|
|
|
|
—
|
|
|
Interest expense—net
|
|
|
|
(658
|
)
|
|
|
|
(1,302
|
)
|
|
|
|
(1,649
|
)
|
|
|
|
(3,787
|
)
|
|
|
|
(3,854
|
)
|
|
Total other expense
|
|
|
|
(654
|
)
|
|
|
|
(1,297
|
)
|
|
|
|
(1,649
|
)
|
|
|
|
(3,759
|
)
|
|
|
|
(3,854
|
)
|
|
INCOME (LOSS) BEFORE TAXES
|
|
|
|
11,516
|
|
|
|
|
(1,542
|
)
|
|
|
|
3,663
|
|
|
|
|
13,977
|
|
|
|
|
35,890
|
|
|
Income tax expense
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
—
|
|
|
NET INCOME (LOSS)
|
|
|
$
|
11,516
|
|
|
|
$
|
(1,542
|
)
|
|
|
$
|
3,663
|
|
|
|
$
|
13,977
|
|
|
|
$
|
35,890
|
|
|
Participating securities—non-vested restricted stock
|
|
|
|
(351
|
)
|
|
|
|
—
|
|
|
|
|
(82
|
)
|
|
|
|
(400
|
)
|
|
|
|
(932
|
)
|
|
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS
|
|
|
$
|
11,165
|
|
|
|
$
|
(1,542
|
)
|
|
|
$
|
3,581
|
|
|
|
$
|
13,577
|
|
|
|
$
|
34,958
|
|
|
Basic and diluted net income (loss) per share attributable to common
shareholders
|
|
|
$
|
0.44
|
|
|
|
$
|
(0.06
|
)
|
|
|
$
|
0.14
|
|
|
|
$
|
0.54
|
|
|
|
$
|
1.39
|
|
|
Basic and diluted weighted average number of common shares
outstanding
|
|
|
|
25,332
|
|
|
|
|
25,332
|
|
|
|
|
25,116
|
|
|
|
|
25,321
|
|
|
|
|
25,074
|
|
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY
|
|
|
|
(In thousands)
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
Series A
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
Preferred
|
|
|
Common
|
|
|
|
|
|
Treasury
|
|
|
Additional
|
|
|
Retained
|
|
|
Stockholders’
|
|
|
|
|
Stock
|
|
|
Stock
|
|
|
Warrants
|
|
|
Stock
|
|
|
Paid-in-Capital
|
|
|
Deficit
|
|
|
Equity
|
|
Balance as of December 31, 2017
|
|
|
$
|
—
|
|
|
$
|
253
|
|
|
$
|
37,329
|
|
|
$
|
(1,603
|
)
|
|
|
$
|
524,755
|
|
|
$
|
(75,147
|
)
|
|
|
$
|
485,587
|
|
|
Share-based compensation
|
|
|
|
—
|
|
|
|
1
|
|
|
|
—
|
|
|
|
—
|
|
|
|
|
5,872
|
|
|
|
—
|
|
|
|
|
5,873
|
|
|
Acquisition of treasury stock
|
|
|
|
—
|
|
|
|
—
|
|
|
|
—
|
|
|
|
(478
|
)
|
|
|
|
—
|
|
|
|
—
|
|
|
|
|
(478
|
)
|
|
Net income
|
|
|
|
—
|
|
|
|
—
|
|
|
|
—
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
13,977
|
|
|
|
|
13,977
|
|
|
Balance as of September 30, 2018
|
|
|
$
|
—
|
|
|
$
|
254
|
|
|
$
|
37,329
|
|
|
$
|
(2,081
|
)
|
|
|
$
|
530,627
|
|
|
$
|
(61,170
|
)
|
|
|
$
|
504,959
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Series A
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
Preferred
|
|
|
Common
|
|
|
|
|
|
Treasury
|
|
|
Additional
|
|
|
Retained
|
|
|
Stockholders’
|
|
|
|
|
Stock
|
|
|
Stock
|
|
|
Warrants
|
|
|
Stock
|
|
|
Paid-in-Capital
|
|
|
Earnings
|
|
|
Equity
|
|
Balance as of December 31, 2016
|
|
|
$
|
—
|
|
|
$
|
250
|
|
|
$
|
37,329
|
|
|
$
|
—
|
|
|
|
$
|
514,305
|
|
|
$
|
9,930
|
|
|
|
$
|
561,814
|
|
|
Share-based compensation
|
|
|
|
—
|
|
|
|
1
|
|
|
|
—
|
|
|
|
—
|
|
|
|
|
8,518
|
|
|
|
—
|
|
|
|
|
8,519
|
|
|
Acquisition of treasury stock
|
|
|
|
—
|
|
|
|
—
|
|
|
|
—
|
|
|
|
(626
|
)
|
|
|
|
—
|
|
|
|
—
|
|
|
|
|
(626
|
)
|
|
Net income
|
|
|
|
—
|
|
|
|
—
|
|
|
|
—
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
35,890
|
|
|
|
|
35,890
|
|
|
Balance as of September 30, 2017
|
|
|
$
|
—
|
|
|
$
|
251
|
|
|
$
|
37,329
|
|
|
$
|
(626
|
)
|
|
|
$
|
522,823
|
|
|
$
|
45,820
|
|
|
|
$
|
605,597
|
|
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
|
|
(In thousands)
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
For the Three
|
|
|
For the Three
|
|
|
For the Nine
|
|
|
For the Nine
|
|
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
Months Ended
|
|
|
|
|
September 30,
|
|
|
June 30,
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
|
2018
|
|
|
2018
|
|
|
2018
|
|
|
2017
|
|
CASH FLOWS FROM OPERATING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
$
|
11,516
|
|
|
|
$
|
(1,542
|
)
|
|
|
$
|
13,977
|
|
|
|
$
|
35,890
|
|
|
Adjustments to reconcile net income/(loss) to net cash provided
by operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Gains) losses on commodity derivative contracts—net
|
|
|
|
6,583
|
|
|
|
|
11,348
|
|
|
|
|
21,870
|
|
|
|
|
(8,767
|
)
|
|
Net cash received (paid) for commodity derivative contracts not
designated as hedging instruments
|
|
|
|
(3,855
|
)
|
|
|
|
(3,518
|
)
|
|
|
|
(7,532
|
)
|
|
|
|
6,149
|
|
|
Asset retirement accretion
|
|
|
|
147
|
|
|
|
|
250
|
|
|
|
|
694
|
|
|
|
|
833
|
|
|
Depreciation, depletion, and amortization
|
|
|
|
15,485
|
|
|
|
|
16,484
|
|
|
|
|
47,182
|
|
|
|
|
46,471
|
|
|
Share-based compensation, net of amounts capitalized to oil and gas
properties
|
|
|
|
905
|
|
|
|
|
1,215
|
|
|
|
|
4,330
|
|
|
|
|
7,102
|
|
|
Amortization of deferred financing costs
|
|
|
|
108
|
|
|
|
|
108
|
|
|
|
|
324
|
|
|
|
|
277
|
|
|
Change in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts receivable—oil and gas sales
|
|
|
|
1,591
|
|
|
|
|
144
|
|
|
|
|
3,028
|
|
|
|
|
4,929
|
|
|
Accounts receivable—JIB and other
|
|
|
|
1,391
|
|
|
|
|
(1,050
|
)
|
|
|
|
(322
|
)
|
|
|
|
2,641
|
|
|
Other current and noncurrent assets
|
|
|
|
225
|
|
|
|
|
996
|
|
|
|
|
(529
|
)
|
|
|
|
(98
|
)
|
|
Accounts payable
|
|
|
|
(1,468
|
)
|
|
|
|
3,768
|
|
|
|
|
833
|
|
|
|
|
1,392
|
|
|
Accrued liabilities
|
|
|
|
(339
|
)
|
|
|
|
(1,052
|
)
|
|
|
|
(2,260
|
)
|
|
|
|
(7,381
|
)
|
|
Other
|
|
|
|
(11
|
)
|
|
|
|
(6
|
)
|
|
|
|
(25
|
)
|
|
|
|
(121
|
)
|
|
Net cash provided by operating activities
|
|
|
$
|
32,278
|
|
|
|
$
|
27,145
|
|
|
|
$
|
81,570
|
|
|
|
$
|
89,317
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Investment in property and equipment
|
|
|
$
|
(32,321
|
)
|
|
|
$
|
(34,085
|
)
|
|
|
$
|
(98,164
|
)
|
|
|
$
|
(92,841
|
)
|
|
Proceeds from the sale of oil and gas properties
|
|
|
|
—
|
|
|
|
|
54,432
|
|
|
|
|
54,432
|
|
|
|
|
2,885
|
|
|
Proceeds from the sale of oil and gas equipment
|
|
|
|
—
|
|
|
|
|
355
|
|
|
|
|
355
|
|
|
|
|
1,350
|
|
|
Net cash used in investing activities
|
|
|
$
|
(32,321
|
)
|
|
|
$
|
20,702
|
|
|
|
$
|
(43,377
|
)
|
|
|
$
|
(88,606
|
)
|
|
CASH FLOWS FROM FINANCING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Repayment of revolving credit facility
|
|
|
|
—
|
|
|
|
|
(50,000
|
)
|
|
|
|
(100,000
|
)
|
|
|
$
|
—
|
|
|
Deferred financing costs
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
(375
|
)
|
|
Repurchase of restricted stock for tax withholdings
|
|
|
|
—
|
|
|
|
|
(19
|
)
|
|
|
|
(478
|
)
|
|
|
|
(626
|
)
|
|
Net cash used in financing activities
|
|
|
$
|
—
|
|
|
|
$
|
(50,019
|
)
|
|
|
$
|
(100,478
|
)
|
|
|
$
|
(1,001
|
)
|
|
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS
|
|
|
$
|
(43
|
)
|
|
|
$
|
(2,172
|
)
|
|
|
$
|
(62,285
|
)
|
|
|
$
|
(290
|
)
|
|
Cash and cash equivalents, beginning of period
|
|
|
$
|
6,256
|
|
|
|
$
|
8,428
|
|
|
|
|
68,498
|
|
|
|
$
|
76,838
|
|
|
Cash and cash equivalents, end of period
|
|
|
$
|
6,213
|
|
|
|
$
|
6,256
|
|
|
|
$
|
6,213
|
|
|
|
$
|
76,548
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
SUPPLEMENTAL INFORMATION:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non-cash transactions — investments in property and equipment
accrued — not paid
|
|
|
$
|
16,261
|
|
|
|
$
|
23,219
|
|
|
|
$
|
16,261
|
|
|
|
$
|
19,865
|
|
|
Cash paid for interest, net
|
|
|
$
|
545
|
|
|
|
$
|
1,225
|
|
|
|
$
|
3,555
|
|
|
|
$
|
3,708
|
|
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
SELECTED FINANCIAL AND OPERATING STATISTICS
|
|
|
|
|
|
|
For the Three Months
|
|
|
For the Nine Months
|
|
|
For the Three Months
|
|
|
|
|
Ended September 30,
|
|
|
Ended September 30,
|
|
|
Ended June 30,
|
|
|
|
|
2018
|
|
|
2017
|
|
|
2018
|
|
|
2017
|
|
|
2018
|
|
Operating Data – Mississippian Lime:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net production volumes:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil (Bbls/day)
|
|
|
|
5,249
|
|
|
|
4,940
|
|
|
|
4,871
|
|
|
|
5,158
|
|
|
|
4,833
|
|
NGLs (Bbls/day)
|
|
|
|
4,257
|
|
|
|
4,145
|
|
|
|
3,954
|
|
|
|
4,398
|
|
|
|
3,995
|
|
Natural gas (Mcf/day)
|
|
|
|
50,939
|
|
|
|
51,130
|
|
|
|
48,341
|
|
|
|
53,474
|
|
|
|
50,246
|
|
Total oil equivalents (MBoe)
|
|
|
|
1,656
|
|
|
|
1,620
|
|
|
|
4,620
|
|
|
|
5,042
|
|
|
|
1,566
|
|
Average daily production (Boe/day)
|
|
|
|
17,996
|
|
|
|
17,606
|
|
|
|
16,882
|
|
|
|
18,469
|
|
|
|
17,202
|
|
Operating Data – Anadarko Basin:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net production volumes:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil (Bbls/day)
|
|
|
|
—
|
|
|
|
1,329
|
|
|
|
1,168
|
|
|
|
1,389
|
|
|
|
1,110
|
|
NGLs (Bbls/day)
|
|
|
|
—
|
|
|
|
992
|
|
|
|
1,017
|
|
|
|
1,066
|
|
|
|
946
|
|
Natural gas (Mcf/day)
|
|
|
|
—
|
|
|
|
8,581
|
|
|
|
8,365
|
|
|
|
9,225
|
|
|
|
7,956
|
|
Total oil equivalents (MBoe)
|
|
|
|
—
|
|
|
|
345
|
|
|
|
540
|
|
|
|
1,090
|
|
|
|
206
|
|
Average daily production (Boe/day)
|
|
|
|
—
|
|
|
|
3,752
|
|
|
|
3,579
|
|
|
|
3,993
|
|
|
|
3,382
|
|
Operating Data - Combined:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net production volumes:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil (Bbls/day)
|
|
|
|
5,249
|
|
|
|
6,269
|
|
|
|
5,516
|
|
|
|
6,547
|
|
|
|
5,943
|
|
NGLs (Bbls/day)
|
|
|
|
4,257
|
|
|
|
5,137
|
|
|
|
4,514
|
|
|
|
5,464
|
|
|
|
4,941
|
|
Natural gas (Mcf/day)
|
|
|
|
50,939
|
|
|
|
59,711
|
|
|
|
52,967
|
|
|
|
62,699
|
|
|
|
58,202
|
|
Total oil equivalents (MBoe)
|
|
|
|
1,656
|
|
|
|
1,965
|
|
|
|
5,159
|
|
|
|
6,132
|
|
|
|
1,772
|
|
Average daily production (Boe/day)
|
|
|
|
17,996
|
|
|
|
21,358
|
|
|
|
18,858
|
|
|
|
22,462
|
|
|
|
20,584
|
|
Average Sales Prices:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil, without realized derivatives (per Bbl)
|
|
|
$
|
68.79
|
|
|
$
|
47.14
|
|
|
$
|
66.12
|
|
|
$
|
47.83
|
|
|
$
|
67.39
|
|
Oil, with realized derivatives (per Bbl)
|
|
|
$
|
60.68
|
|
|
$
|
50.11
|
|
|
$
|
60.05
|
|
|
$
|
50.09
|
|
|
$
|
59.95
|
|
Natural gas liquids, without realized derivatives (per Bbl)
|
|
|
$
|
32.48
|
|
|
$
|
22.55
|
|
|
$
|
28.83
|
|
|
$
|
21.17
|
|
|
$
|
28.24
|
|
Natural gas liquids, with realized derivatives (per Bbl)
|
|
|
$
|
32.48
|
|
|
$
|
22.55
|
|
|
$
|
28.83
|
|
|
$
|
21.17
|
|
|
$
|
28.24
|
|
Natural gas, without realized derivatives (per Mcf)
|
|
|
$
|
1.49
|
|
|
$
|
2.54
|
|
|
$
|
1.53
|
|
|
$
|
2.71
|
|
|
$
|
1.34
|
|
Natural gas, with realized derivatives (per Mcf)
|
|
|
$
|
1.51
|
|
|
$
|
2.76
|
|
|
$
|
1.64
|
|
|
$
|
2.83
|
|
|
$
|
1.39
|
|
Costs and Expenses (per Boe of production):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating
|
|
|
$
|
5.81
|
|
|
$
|
6.66
|
|
|
$
|
6.37
|
|
|
$
|
6.64
|
|
|
$
|
6.45
|
|
Workover
|
|
|
$
|
1.35
|
|
|
$
|
1.31
|
|
|
$
|
2.09
|
|
|
$
|
1.20
|
|
|
$
|
3.12
|
|
Gathering and transportation
|
|
|
$
|
0.03
|
|
|
$
|
1.88
|
|
|
$
|
0.03
|
|
|
$
|
1.80
|
|
|
$
|
0.04
|
|
Severance and other taxes
|
|
|
$
|
2.03
|
|
|
$
|
1.20
|
|
|
$
|
1.74
|
|
|
$
|
1.01
|
|
|
$
|
1.57
|
|
Asset retirement accretion
|
|
|
$
|
0.09
|
|
|
$
|
0.14
|
|
|
$
|
0.13
|
|
|
$
|
0.14
|
|
|
$
|
0.14
|
|
Depreciation, depletion and amortization
|
|
|
$
|
9.36
|
|
|
$
|
7.72
|
|
|
$
|
9.15
|
|
|
$
|
7.58
|
|
|
$
|
9.30
|
|
General and administrative
|
|
|
$
|
2.84
|
|
|
$
|
3.69
|
|
|
$
|
3.83
|
|
|
$
|
3.77
|
|
|
$
|
2.93
|
|
Advisory fees
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
0.16
|
|
|
|
—
|
|
|
$
|
0.48
|
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
ADJUSTED EBITDA
|
|
|
|
(In thousands)
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
For the Three Months
|
|
|
For the Nine Months
|
|
|
For the Three Months
|
|
|
|
|
Ended September 30,
|
|
|
Ended September 30,
|
|
|
Ended June 30,
|
|
|
|
|
2018
|
|
|
2017
|
|
|
2018
|
|
|
2017
|
|
|
2018
|
|
Adjusted EBITDA to net income (loss) reconciliation:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
$
|
11,516
|
|
|
|
$
|
3,663
|
|
|
$
|
13,977
|
|
|
|
$
|
35,890
|
|
|
|
$
|
(1,542
|
)
|
|
Depreciation, depletion and amortization
|
|
|
|
15,485
|
|
|
|
|
15,170
|
|
|
|
47,182
|
|
|
|
|
46,471
|
|
|
|
|
16,484
|
|
|
Losses (gains) on commodity derivative contracts—net
|
|
|
|
6,583
|
|
|
|
|
3,591
|
|
|
|
21,870
|
|
|
|
|
(8,767
|
)
|
|
|
|
11,348
|
|
|
Net cash received (paid) for commodity derivative contracts not
designated as hedging instruments
|
|
|
|
(3,854
|
)
|
|
|
|
2,909
|
|
|
|
(7,532
|
)
|
|
|
|
6,149
|
|
|
|
|
(3,518
|
)
|
|
Income tax expense
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
—
|
|
|
Interest income
|
|
|
|
(4
|
)
|
|
|
|
—
|
|
|
|
(28
|
)
|
|
|
|
—
|
|
|
|
|
(5
|
)
|
|
Interest expense, net of amounts capitalized
|
|
|
|
658
|
|
|
|
|
1,649
|
|
|
|
3,787
|
|
|
|
|
3,854
|
|
|
|
|
1,302
|
|
|
Asset retirement obligation accretion
|
|
|
|
147
|
|
|
|
|
274
|
|
|
|
694
|
|
|
|
|
833
|
|
|
|
|
250
|
|
|
Share-based compensation, net of amounts capitalized
|
|
|
|
905
|
|
|
|
|
2,835
|
|
|
|
4,330
|
|
|
|
|
7,102
|
|
|
|
|
1,215
|
|
|
Adjusted EBITDA
|
|
|
$
|
31,436
|
|
|
|
$
|
30,091
|
|
|
$
|
84,280
|
|
|
|
$
|
91,532
|
|
|
|
$
|
25,534
|
|
|
Lagging costs associated with restructuring
|
|
|
|
—
|
|
|
|
|
139
|
|
|
|
335
|
|
|
|
|
2,730
|
|
|
|
|
298
|
|
|
Costs incurred for strategic reviews
|
|
|
|
489
|
|
|
|
|
—
|
|
|
|
3,121
|
|
|
|
|
—
|
|
|
|
|
312
|
|
|
Advisory costs
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
850
|
|
|
|
|
—
|
|
|
|
|
850
|
|
|
Adjusted EBITDA before restructuring and advisory costs
|
|
|
$
|
31,925
|
|
|
|
$
|
30,230
|
|
|
$
|
88,586
|
|
|
|
$
|
94,262
|
|
|
|
$
|
26,994
|
|
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
CASH OPERATING EXPENSES
|
|
|
|
(In thousands)
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
For the Three Months
|
|
|
For the Nine Months
|
|
|
For the Three Months
|
|
|
|
|
Ended September 30,
|
|
|
Ended September 30,
|
|
|
Ended June 30,
|
|
|
|
|
2018
|
|
|
2017
|
|
|
2018
|
|
|
2017
|
|
|
2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Expenses – GAAP
|
|
|
$
|
35,595
|
|
|
$
|
44,403
|
|
|
$
|
121,258
|
|
|
$
|
135,665
|
|
|
$
|
42,569
|
|
Adjustments for certain non-cash items:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asset retirement accretion
|
|
|
|
147
|
|
|
|
274
|
|
|
|
694
|
|
|
|
833
|
|
|
|
250
|
|
Share-based compensation, net
|
|
|
|
905
|
|
|
|
2,835
|
|
|
|
4,330
|
|
|
|
7,102
|
|
|
|
1,215
|
|
Depreciation, depletion and amortization
|
|
|
|
15,485
|
|
|
|
15,170
|
|
|
|
47,182
|
|
|
|
46,471
|
|
|
|
16,484
|
|
Cash Operating Expenses – Non-GAAP
|
|
|
$
|
19,058
|
|
|
$
|
26,124
|
|
|
$
|
69,052
|
|
|
$
|
81,259
|
|
|
$
|
24,620
|
|
Cash Operating Expenses – Non-GAAP per BOE
|
|
|
$
|
11.51
|
|
|
$
|
13.29
|
|
|
$
|
13.38
|
|
|
$
|
13.25
|
|
|
$
|
13.89
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Advisory fees
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
850
|
|
|
$
|
—
|
|
|
$
|
850
|
|
Advisory fees, per BOE
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
0.16
|
|
|
$
|
—
|
|
|
$
|
0.48
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lagging costs associated with restructuring
|
|
|
$
|
—
|
|
|
$
|
139
|
|
|
$
|
335
|
|
|
$
|
2,730
|
|
|
$
|
298
|
|
Lagging costs associated with restructuring, per BOE
|
|
|
$
|
—
|
|
|
$
|
0.07
|
|
|
$
|
0.06
|
|
|
$
|
0.45
|
|
|
$
|
0.17
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Severance costs
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1,621
|
|
|
$
|
—
|
|
|
$
|
25
|
|
Severance costs, per BOE
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
0.31
|
|
|
$
|
—
|
|
|
$
|
0.01
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs incurred for strategic reviews
|
|
|
$
|
489
|
|
|
$
|
—
|
|
|
$
|
3,121
|
|
|
$
|
—
|
|
|
$
|
312
|
|
Costs incurred for strategic reviews, per BOE
|
|
|
$
|
0.30
|
|
|
$
|
—
|
|
|
$
|
0.60
|
|
|
$
|
—
|
|
|
$
|
0.18
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted Cash Operating Expenses – Non-GAAP
|
|
|
$
|
18,569
|
|
|
$
|
25,985
|
|
|
$
|
63,125
|
|
|
$
|
78,529
|
|
|
$
|
23,135
|
|
Adjusted Cash Operating Expenses – Non-GAAP per BOE
|
|
|
$
|
11.21
|
|
|
$
|
13.22
|
|
|
$
|
12.23
|
|
|
$
|
12.81
|
|
|
$
|
13.05
|
|
|
|
|
|
MIDSTATES PETROLEUM COMPANY, INC.
|
|
ADJUSTED CASH GENERAL AND ADMINISTRATIVE EXPENSES
|
|
|
|
(In thousands)
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
For the Three Months
|
|
|
For the Nine Months
|
|
|
For the Three Months
|
|
|
|
|
Ended September 30,
|
|
|
Ended September 30,
|
|
|
Ended June 30,
|
|
|
|
|
|
2018
|
|
|
|
|
2017
|
|
|
|
|
2018
|
|
|
|
|
2017
|
|
|
|
|
2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General and Administrative Expenses – GAAP
|
|
|
$
|
4,688
|
|
|
|
$
|
7,255
|
|
|
|
$
|
19,735
|
|
|
|
$
|
23,102
|
|
|
|
$
|
5,190
|
|
|
Adjustments for certain non-cash and non-recurring items:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Share-based compensation, net
|
|
|
|
(905
|
)
|
|
|
|
(2,835
|
)
|
|
|
|
(4,330
|
)
|
|
|
|
(7,102
|
)
|
|
|
|
(1,215
|
)
|
|
Capitalized general and administrative expenses
|
|
|
|
571
|
|
|
|
|
898
|
|
|
|
|
1,871
|
|
|
|
|
2,664
|
|
|
|
|
636
|
|
|
Severance costs
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
(1,621
|
)
|
|
|
|
—
|
|
|
|
|
(25
|
)
|
|
Costs incurred for strategic reviews
|
|
|
|
(489
|
)
|
|
|
|
—
|
|
|
|
|
(3,121
|
)
|
|
|
|
—
|
|
|
|
|
(312
|
)
|
|
Lagging costs associated with restructuring included in general and
administrative expenses
|
|
|
|
—
|
|
|
|
|
(139
|
)
|
|
|
|
(335
|
)
|
|
|
|
(2,730
|
)
|
|
|
|
(298
|
)
|
|
Adjusted Cash General and Administrative Expenses – Non-GAAP
|
|
|
$
|
3,865
|
|
|
|
$
|
5,179
|
|
|
|
$
|
12,199
|
|
|
|
$
|
15,934
|
|
|
|
$
|
3,976
|
|
|
Adjusted Cash General and Administrative Expenses – Non-GAAP
per BOE
|
|
|
$
|
2.33
|
|
|
|
$
|
2.64
|
|
|
|
$
|
2.36
|
|
|
|
$
|
2.60
|
|
|
|
$
|
2.24
|
|
View source version on businesswire.com: https://www.businesswire.com/news/home/20181108006014/en/ Copyright Business Wire 2018
Source: Business Wire
(November 8, 2018 - 4:45 PM EST)
News by QuoteMedia
www.quotemedia.com
|
