Exhibit 99.1
321 SOUTH BOSTON AVENUE, SUITE 1000
TULSA, OKLAHOMA 74103
PRESS RELEASE FOR IMMEDIATE ISSUANCE
MIDSTATES PETROLEUM ANNOUNCES SECOND QUARTER
2018 RESULTS
TULSA, OK — (BUSINESS WIRE) — August 2, 2018 — Midstates Petroleum Company, Inc. (“Midstates” or the “Company”) (NYSE: MPO) today announced its second quarter 2018 operational and financial results.
Second Quarter 2018 Highlights and Recent Key Items
· Continued execution of the market-focused strategy aimed at reducing costs, generating substantial free cash flow, improving liquidity and focusing activity to maximize optionality
· Closed strategic sale of the Company’s Anadarko Basin producing properties for $58.0 million; net proceeds were approximately $54 million, subject to post-closing adjustments
· Executed $50 million pay-down to reserve-based lending (RBL) facility in June 2018; total RBL pay-downs of $100 million thus far in 2018, expected to reduce annualized interest expense by approximately $6 million
· Grew Mississippian Lime production to 17,202 barrels of oil equivalent per day (BOEPD) in the second quarter of 2018, an 11% increase from 15,518 BOEPD in the first quarter of 2018, due largely to a highly-successful expanded workover program
· Utilized 10 workover rigs in the second quarter to increase base production by performing highly economic projects
· Currently operating one workover rig as the expanded workover program is largely complete
· Brought online the Company’s first two Mississippian Lime two-mile laterals at an average completed well cost of $3.6 million (an implied $1.8 million per one-mile lateral); achieving an average two-stream initial 24-hour peak rate of approximately 950 BOEPD (36% oil) per well
For the second quarter of 2018, Midstates reported a net loss of $1.5 million, or $0.06 per share, which included the impact of a $7.8 million non-cash charge related to the Company’s commodity derivative contracts. In the same period in 2017, the Company reported net income of $13.7 million, or $0.53 per share, and in the first quarter of 2018 reported net income of $4.0 million, or $0.15 per share. In the second quarter of 2018, Midstates generated Adjusted EBITDA of $27.0 million, excluding advisory fees and costs incurred for strategic reviews. This compares to $29.1 million for the same quarter in 2017 and $29.7 million for the first quarter of 2018.
David Sambrooks, President and Chief Executive Officer, commented, “I am very pleased with what we have accomplished thus far in 2018. We have closed the sale of our non-core Anadarko asset, paid down a considerable portion of our outstanding debt, grown our Mississippian Lime production and lowered lease operating expenses and G&A costs. We are measurably executing on our market-focused strategy and creating value for our stakeholders. Operationally, we have restored over 2,100 BOEPD of base production by performing over 180 workovers to date. Our Mississippian Lime production was up 11% quarter over quarter, and with the expanded workover program largely complete, we are forecasting expense reductions
in the second half of the year. Additionally, we brought online Midstates’ first 2 two-mile lateral wells during the quarter. Operational results were excellent with an average drill and complete cost for the 2 wells of only $1.8 million per one mile lateral. Compared to our 2017 average one-mile well cost of $3.2 million, this roughly 45% savings in per mile costs is a substantial value enhancement for our individual well economics. Further, initial production results are above expectations with an average two-stream 24-hour peak rate of approximately 950 BOEPD per well. The combination of improved production, higher oil prices and lower costs yields very strong margins that will drive EBITDA and free cash flow for the remainder of the year.”
(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 17,202 BOEPD in the second quarter of 2018, an 11% increase from 15,518 BOEPD in the first quarter of 2018
· Production of 17,202 BOEPD in the second quarter of 2018 consisted of 28% oil, 23% natural gas liquids (NGLs), and 49% natural gas
· Utilized 10 workover rigs in the second quarter to increase base production by performing highly economic projects
· Currently operating one workover rig as the expanded workover program is largely complete
· Spud four wells (including two extended lateral wells) and placed eight wells online (including two extended lateral wells) during the second quarter of 2018
· Brought online the Company’s first two Mississippian Lime two-mile laterals at an average completed well cost of $3.6 million (an implied $1.8 million per one-mile lateral); achieving an average two-stream initial 24-hour peak rate of approximately 950 BOEPD (36% oil) per well
The Company continued to run its one-rig drilling program in the Mississippian Lime through the second quarter of 2018 with the goal of minimizing drilling and completion costs to enhance economics in delineated areas. In addition to the two extended laterals placed in production during the second quarter of 2018, the Company plans to drill and complete two additional extended lateral wells by the end of the year.
Further, as part of the Company’s base production optimization program, Midstates had 10 workover rigs operating in the field during the second quarter of 2018 and has since reduced the workover rig count to one workover rig in early August after successfully restoring more than 2,100 BOEPD of base production in the first half of the year. During the second quarter of 2018, the Company performed workovers on 115 wells, and a total of 184 workovers have been completed to-date in 2018.
The Company did not bring online any additional saltwater disposal injection wells during the second quarter of 2018. Midstates is currently operating 11 non-Arbuckle injection wells in Woods and Alfalfa Counties, Oklahoma, with a total permitted injection capacity of approximately 240,000 barrels of water per day. The Company’s total permitted injection capacity 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, with a current disposal rate into all formations of approximately 180,000 barrels of water per day. Approximately 35% of the Company’s water injection is currently being injected into non-Arbuckle formations.
Closing of Anadarko Basin Producing Properties Sale
On June 5, 2018, Midstates announced the closing of its Anadarko Basin producing properties located in the Texas panhandle and western Oklahoma for $58 million. The net proceeds were approximately $54 million, subject to standard post-closing adjustments. These properties had year-end 2017 proved developed PV-10 at SEC pricing of approximately $53 million. Proceeds from the sale were used to pay down $50 million of outstanding borrowings under the Company’s revolving credit facility and for general corporate purposes.
The Company retained its undeveloped acreage in the NW STACK in Dewey County, Oklahoma.
Production and Pricing
Production during the second quarter of 2018 totaled 20,584 BOEPD, compared with 19,235 BOEPD during the first quarter of 2018. Production from the Company’s Mississippian Lime properties contributed approximately 84%, or 17,202 BOEPD, and the Anadarko Basin properties contributed approximately 16%, or 3,382 BOEPD. For the total Company, oil volumes comprised 29% of total production, NGLs 24%, and natural gas 47% during the second quarter of 2018. Midstates’ second quarter of 2018 Mississippian Lime production grew approximately 11% from the first quarter of 2018 primarily due to the execution of the Company’s base production optimization program during the first and second quarters.
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 second quarter of 2018 were $52.9 million, before the impact of derivatives and including $3.4 million of gathering and transportation expense, compared to $51.8 million in the first quarter of 2018, which included $3.0 million of gathering and transportation expense. The net loss on derivatives for the second quarter of 2018 was $11.3 million, compared with a $3.9 million loss during the first quarter of 2018.
The following table sets forth information regarding average realized sales prices for the periods indicated:
| | Crude Oil | | NGLs | | Natural Gas | |
| | Three Months
Ended | | Three Months
Ended | | Three Months
Ended | | Three Months
Ended | | Three Months
Ended | | Three Months
Ended | |
| | June 30, 2018 | | March 31, 2018 | | June 30, 2018 | | March 31, 2018 | | June 30, 2018 | | March 31, 2018 | |
Average sales price exclusive of realized derivatives and certain deductions from revenue | | $ | 67.42 | | $ | 62.43 | | $ | 28.28 | | $ | 26.11 | | $ | 2.01 | | $ | 2.41 | |
Realized derivatives | | (7.44 | ) | (2.84 | ) | — | | — | | 0.05 | | 0.28 | |
Average sales price with realized derivatives exclusive of certain deductions from revenue | | $ | 59.98 | | $ | 59.59 | | $ | 28.28 | | $ | 26.11 | | $ | 2.06 | | $ | 2.69 | |
Certain deductions from revenue | | (0.03 | ) | (0.02 | ) | (0.04 | ) | (0.07 | ) | (0.67 | ) | (0.65 | ) |
Average sales price inclusive of realized derivatives and certain deductions from revenue | | $ | 59.95 | | $ | 59.57 | | $ | 28.24 | | $ | | 26.04 | | $ | 1.39 | | $ | | 2.04 | |
| | | | | | | | | | | | | | | | | | | | | |
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.
| | NYMEX WTI | |
| | Fixed Swaps | | Three-Way Collars | |
| | Hedge
Position
(Bbls) | | Weighted
Avg
Strike
Price | | Hedge
Position
(Bbls) | | Weighted
Avg
Ceiling
Price | | Weighted
Avg Floor
Price | | Weighted
Avg
Sub-Floor
Price | |
Quarter Ended: | | | | | | | | | | | | | |
June 30, 2018 | | 159,250 | | $ | 52.50 | | 182,000 | | $ | 60.65 | | $ | 50.00 | | $ | 40.00 | |
September 30, 2018(1) | | 175,720 | | $ | 57.23 | | 184,000 | | $ | 59.93 | | $ | 50.00 | | $ | 40.00 | |
December 31, 2018(1) | | 313,720 | | $ | 58.59 | | 46,000 | | $ | 56.70 | | $ | 50.00 | | $ | 40.00 | |
March 31, 2019(1) | | 171,000 | | $ | 66.48 | | 180,000 | | $ | 63.14 | | $ | 53.75 | | $ | 43.75 | |
June 30, 2019(1) | | 133,900 | | $ | 64.86 | | 182,000 | | $ | 63.14 | | $ | 53.75 | | $ | 43.75 | |
September 30, 2019(1) | | 46,000 | | $ | 62.96 | | 184,000 | | $ | 63.14 | | $ | 53.75 | | $ | 43.75 | |
December 31, 2019(1) | | 46,000 | | $ | 61.43 | | 184,000 | | $ | 63.14 | | $ | 53.75 | | $ | 43.75 | |
March 31, 2020(1) | | — | | $ | — | | 91,000 | | $ | 65.75 | | $ | 50.00 | | $ | 40.00 | |
June 30, 2020(1) | | — | | $ | — | | 91,000 | | $ | 65.75 | | $ | 50.00 | | $ | 40.00 | |
September 30, 2020(1) | | — | | $ | — | | 92,000 | | $ | 65.75 | | $ | 50.00 | | $ | 40.00 | |
December 31, 2020(1) | | — | | $ | — | | 92,000 | | $ | 65.75 | | $ | 50.00 | | $ | 40.00 | |
| | NYMEX HENRY HUB | |
| | Fixed Swaps | | Three-Way Collars | |
| | Hedge
Position
(MMBtu) | | Weighted
Avg Strike
Price | | Hedge
Position
(MMBtu) | | Weighted
Avg
Ceiling
Price | | Weighted
Avg
Floor
Price | | Weighted
Avg
Sub-Floor
Price | |
Quarter Ended: | | | | | | | | | | | | | |
June 30, 2018 | | 1,155,000 | | $ | 2.82 | | 1,365,000 | | $ | 3.40 | | $ | 3.00 | | $ | 2.50 | |
September 30, 2018(1) | | 2,116,000 | | $ | 2.84 | | 1,380,000 | | $ | 3.40 | | $ | 3.00 | | $ | 2.50 | |
December 31, 2018(1) | | 2,055,000 | | $ | 2.95 | | 1,380,000 | | $ | 3.40 | | $ | 3.00 | | $ | 2.50 | |
March 31, 2019(1) | | 1,980,000 | | $ | 3.01 | | 1,350,000 | | $ | 3.40 | | $ | 3.00 | | $ | 2.50 | |
(1) Positions shown represent open commodity derivative contract positions as of June 30, 2018.
Costs and Expenses
Adjusted Cash Operating Expenses (which excludes debt restructuring and advisory fees, as well as severance costs) for the second quarter of 2018 were $23.1 million, or $13.05 per barrel of oil equivalent (Boe), compared with $21.4 million, or $12.37 per Boe, in the first quarter of 2018. The increase in adjusted cash operating expenses for the second quarter of 2018 was attributable to higher workover expenses as the Company completed 115 workover projects to optimize production.
LOE and workover expenses (EWO) combined totaled $17.0 million, or $9.57 per Boe, in the second quarter of 2018, compared with $14.8 million, or $8.56 per Boe, in the first quarter of 2018. LOE per Boe decreased by $0.38, during the second quarter of 2018 compared to the first quarter of 2018 primarily
due to the divestiture of the Anadarko Basin producing properties. Second quarter 2018 workover expenses increased $1.39 per BOE from the first quarter of 2018 due to the Company’s continued base production optimization program. Midstates’ expanded workover program was substantially completed during second quarter of 2018 and the Company is currently operating one workover rig as of August 1, 2018.
Severance and other taxes for the second quarter of 2018 were $2.8 million, or $1.57 per Boe (5.2% of oil, NGLs and natural gas sales revenue), compared to $2.9 million, or $1.65 per Boe (5.5% of oil, NGLs and natural gas sales revenue) in the first quarter of 2018. While severance and other tax rates have remained consistent quarter over quarter as a percentage of revenue, the rates remained elevated from prior years 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 (G&A) expenses for the second quarter of 2018 totaled $5.2 million, or $2.93 per Boe, compared to $9.9 million, or $5.70 per Boe, in the first quarter of 2018. G&A expenses decreased in the second quarter of 2018 due to lower costs associated with the Company’s ongoing strategic review, as well as one-time severance costs during the first quarter of 2018. Second quarter 2018 and first quarter 2018 general and administrative expenses included net non-cash, share-based compensation expense of $1.2 million, or $0.69 per Boe, and $2.2 million, or $1.28 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 $4.0 million, or $2.24 per Boe for the second quarter of 2018, compared to $4.4 million, or $2.52 per Boe, in the first quarter of 2018. Second quarter 2018 adjusted cash general and administrative expenses decreased compared to first quarter of 2018 primarily due to lower employee expenses as a result of the workforce reduction in the first quarter of 2018.
Depreciation, depletion and amortization expense for the second quarter of 2018 totaled $16.5 million, or $9.30 per Boe, compared to $15.2 million, or $8.79 per Boe in the first quarter of 2018. Depreciation, depletion and amortization expense increased primarily as a result of higher production for the second quarter of 2018.
Interest expense totaled $1.3 million (net of amounts capitalized) for the second quarter of 2018, compared to $1.8 million in the first quarter of 2018. The Company capitalized $0.1 million in interest to unproved properties in both the second quarter and first 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 second quarter of 2018 and the first quarter of 2018.
Capital Expenditures
In the second quarter of 2018, the Company invested $39.2 million of operating capital, predominantly devoted to 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 six months ended June 30, 2018 (in thousands):
| | For the Three
Months Ended
June 30, 2018 | | For the Six
Months Ended
June 30, 2018 | |
Drilling and completion activities | | $ | 36,651 | | $ | 67,405 | |
Acquisition of acreage and seismic data | | 2,515 | | 3,952 | |
Operational capital expenditures incurred | | $ | 39,166 | | $ | 71,357 | |
Capitalized G&A, office, ARO & other | | 969 | | 2,189 | |
Capitalized interest | | 114 | | 191 | |
Total capital expenditures incurred | | $ | 40,249 | | $ | 73,737 | |
| | For the Three
Months Ended
June 30, 2018 | | For the Six
Months Ended
June 30, 2018 | |
Mississippian Lime | | $ | 39,192 | | $ | 71,397 | |
Anadarko Basin | | (26 | ) | (40 | ) |
Total operational capital expenditures incurred | | $ | 39,166 | | $ | 71,357 | |
Balance Sheet and Liquidity
On June 30, 2018, the Company’s liquidity was approximately $146.3 million, consisting of cash and cash equivalents of $6.3 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 $21.8 million.
As of June 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 April 19, 2018, the Company’s borrowing base under its revolving credit facility was reaffirmed at $170 million. The agreement with its bank group excludes the Company’s Anadarko Basin assets in Texas and Oklahoma from the redetermination of the borrowing base. The next scheduled borrowing base redetermination will occur on or about October 1, 2018.
Updated Full-Year 2018 Guidance
Production Guidance (Boe/d) | | 16,500 – 17,500 |
| | |
Operational CAPEX Guidance | | $100 million - $110 million |
| | |
Price Differential Guidance |
Oil (per Bbl) | | $0.70 |
NGLs (realized % of WTI) | | 40% |
Natural Gas inclusive of G&T(1) (per MMBTU) | | $1.35 |
Cost Guidance per Boe |
Lease Operating Expenses | | $5.00 - $5.50 |
Expense Workover | | $2.00 - $2.25 |
Severance & Other Taxes | | $1.50 - $1.70 |
Adjusted G&A — Cash(2) | | $2.60 - $2.90 |
(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.
Conference Call Information
The Company will host a conference call to discuss second quarter 2018 results on Friday, August 3, 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 4371046 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 4371046 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.
*********
Contact:
Midstates Petroleum Company, Inc.
Jason McGlynn, Investor Relations, (918) 947-4614
Jason.McGlynn@midstatespetroleum.com
MIDSTATES PETROLEUM COMPANY, INC.
CONSOLIDATED BALANCE SHEETS
(In thousands, except share amounts)
(Unaudited)
| | June 30, 2018 | | March 31, 2018 | | December 31, 2017 | |
ASSETS | | | | | | | |
CURRENT ASSETS: | | | | | | | |
Cash and cash equivalents | | $ | 6,256 | | $ | 8,428 | | $ | 68,498 | |
Accounts receivable: | | | | | | | |
Oil and gas sales | | 30,278 | | 30,467 | | 32,455 | |
Joint interest billing | | 4,598 | | 3,691 | | 3,297 | |
Other | | 298 | | 259 | | 166 | |
Commodity derivative contracts | | — | | — | | 762 | |
Other current assets | | 2,474 | | 3,124 | | 1,510 | |
Total current assets | | 43,904 | | 45,969 | | 106,688 | |
PROPERTY AND EQUIPMENT: | | | | | | | |
Oil and gas properties, on the basis of full-cost accounting | | | | | | | |
Proved properties | | 778,741 | | 798,593 | | 765,308 | |
Unproved properties not being amortized | | 4,383 | | 7,142 | | 7,065 | |
Other property and equipment | | 6,243 | | 6,502 | | 6,508 | |
Less accumulated depreciation, depletion and amortization | | (235,948 | ) | (219,590 | ) | (204,419 | ) |
Net property and equipment | | 553,419 | | 592,647 | | 574,462 | |
OTHER NONCURRENT ASSETS | | 5,263 | | 7,006 | | 6,978 | |
TOTAL | | $ | 602,586 | | $ | 645,622 | | $ | 688,128 | |
LIABILITIES AND EQUITY | | | | | | | |
CURRENT LIABILITIES: | | | | | | | |
Accounts payable | | $ | 19,216 | | $ | 6,652 | | $ | 11,547 | |
Accrued liabilities | | 40,327 | | 45,533 | | 42,842 | |
Commodity derivative contracts | | 11,549 | | 6,062 | | 3,433 | |
Total current liabilities | | 71,092 | | 58,247 | | 57,822 | |
LONG-TERM LIABILITIES: | | | | | | | |
Asset retirement obligations | | 7,573 | | 15,853 | | 15,506 | |
Commodity derivative contracts | | 3,293 | | 950 | | 562 | |
Long-term debt | | 28,059 | | 78,059 | | 128,059 | |
Other long-term liabilities | | 578 | | 585 | | 592 | |
Total long-term liabilities | | 39,503 | | 95,447 | | 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 | ) | (2,062 | ) | (1,603 | ) |
Additional paid-in-capital | | 529,175 | | 527,550 | | 524,755 | |
Retained deficit | | (72,686 | ) | (71,143 | ) | (75,147 | ) |
Total stockholders’ equity | | 491,991 | | 491,928 | | 485,587 | |
TOTAL | | $ | 602,586 | | $ | 645,622 | | $ | 688,128 | |
MIDSTATES PETROLEUM COMPANY, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands)
(Unaudited)
| | For the Three
Months Ended | | For the Three
Months Ended | | For the Six
Months Ended | | For the Six
Months Ended | | For the Three
Months Ended | |
| | June 30, 2018 | | June 30, 2017 | | June 30, 2018 | | June 30, 2017 | | March 31, 2018 | |
REVENUES: | | | | | | | | | | | |
Oil sales | | $ | 34,202 | | $ | 27,271 | | $ | 66,616 | | $ | 58,307 | | $ | 32,414 | |
Natural gas liquid sales | | 11,893 | | 9,730 | | 22,931 | | 20,924 | | 11,038 | |
Natural gas sales | | 6,782 | | 15,253 | | 15,119 | | 32,351 | | 8,337 | |
Other revenue | | 795 | | 932 | | 1,850 | | 1,754 | | 1,055 | |
Total revenues from contracts with customers | | 53,672 | | 53,186 | | 106,516 | | 113,336 | | 52,844 | |
Gains (losses) on commodity derivative contracts—net | | (11,348 | ) | 7,493 | | (15,287 | ) | 12,358 | | (3,939 | ) |
Total revenues | | 42,324 | | 60,679 | | 91,229 | | 125,694 | | 48,905 | |
EXPENSES: | | | | | | | | | | | |
Lease operating and workover | | 16,952 | | 16,559 | | 31,760 | | 32,411 | | 14,808 | |
Gathering and transportation | | 67 | | 3,641 | | 124 | | 7,328 | | 57 | |
Severance and other taxes | | 2,776 | | 1,695 | | 5,638 | | 3,816 | | 2,861 | |
Asset retirement accretion | | 250 | | 283 | | 547 | | 559 | | 297 | |
Depreciation, depletion, and amortization | | 16,484 | | 15,959 | | 31,697 | | 31,301 | | 15,213 | |
General and administrative | | 5,190 | | 7,572 | | 15,047 | | 15,847 | | 9,857 | |
Advisory fees | | 850 | | — | | 850 | | — | | — | |
Total expenses | | 42,569 | | 45,709 | | 85,663 | | 91,262 | | 43,093 | |
OPERATING INCOME (LOSS) | | (245 | ) | 14,970 | | 5,566 | | 34,432 | | 5,812 | |
OTHER EXPENSE: | | | | | | | | | | | |
Interest income | | 5 | | — | | 24 | | — | | 19 | |
Interest expense—net | | (1,302 | ) | (1,228 | ) | (3,129 | ) | (2,205 | ) | (1,827 | ) |
Total other expense | | (1,297 | ) | (1,228 | ) | (3,105 | ) | (2,205 | ) | (1,808 | ) |
INCOME (LOSS) BEFORE TAXES | | (1,542 | ) | 13,742 | | 2,461 | | 32,227 | | 4,004 | |
Income tax expense | | — | | — | | — | | — | | — | |
NET INCOME (LOSS) | | $ | (1,542 | ) | $ | 13,742 | | $ | 2,461 | | $ | 32,227 | | $ | 4,004 | |
Participating securities—non-vested restricted stock | | — | | (360 | ) | (68 | ) | (897 | ) | (99 | ) |
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS | | $ | (1,542 | ) | $ | 13,382 | | $ | 2,393 | | $ | 31,330 | | $ | 3,905 | |
Basic and diluted net income (loss) per share attributable to common shareholders | | $ | (0.06 | ) | $ | 0.53 | | $ | 0.09 | | $ | 1.25 | | $ | 0.15 | |
Basic and diluted weighted average number of common shares outstanding | | 25,332 | | 25,093 | | 25,316 | | 25,053 | | 25,299 | |
MIDSTATES PETROLEUM COMPANY, INC.
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY
(In thousands)
(Unaudited)
| | Series A
Preferred
Stock | | Common
Stock | | Warrants | | Treasury
Stock | | Additional
Paid-in-Capital | | Retained
Deficit | | Total
Stockholders’
Equity | |
Balance as of December 31, 2017 | | $ | — | | $ | 253 | | $ | 37,329 | | $ | (1,603 | ) | $ | 524,755 | | $ | (75,147 | ) | $ | 485,587 | |
Share-based compensation | | — | | 1 | | — | | — | | 4,420 | | — | | 4,421 | |
Acquisition of treasury stock | | — | | — | | — | | (478 | ) | — | | — | | (478 | ) |
Net income | | — | | — | | — | | — | | — | | 2,461 | | 2,461 | |
Balance as of June 30, 2018 | | $ | — | | $ | 254 | | $ | 37,329 | | $ | (2,081 | ) | $ | 529,175 | | $ | (72,686 | ) | $ | 491,991 | |
| | Series A
Preferred
Stock | | Common
Stock | | Warrants | | Treasury
Stock | | Additional
Paid-in-Capital | | Retained
Earnings | | Total
Stockholders’
Equity | |
Balance as of December 31, 2016 | | $ | — | | $ | 250 | | $ | 37,329 | | $ | — | | $ | 514,305 | | $ | 9,930 | | $ | 561,814 | |
Share-based compensation | | — | | 1 | | — | | — | | 5,251 | | — | | 5,252 | |
Acquisition of treasury stock | | — | | — | | — | | (622 | ) | — | | — | | (622 | ) |
Net income | | — | | — | | — | | — | | — | | 32,227 | | 32,227 | |
Balance as of June 30, 2017 | | $ | — | | $ | 251 | | $ | 37,329 | | $ | (622 | ) | $ | 519,556 | | $ | 42,157 | | $ | 598,671 | |
MIDSTATES PETROLEUM COMPANY, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(Unaudited)
| | For the Three
Months Ended | | For the Three
Months Ended | | For the Six
Months Ended | | For the Six
Months Ended | | For the Three
Months Ended | |
| | June 30, 2018 | | June 30, 2017 | | June 30, 2018 | | June 30, 2017 | | March 31, 2018 | |
CASH FLOWS FROM OPERATING ACTIVITIES: | | | | | | | | | | | |
Net income | | $ | (1,542 | ) | $ | 13,742 | | $ | 2,461 | | $ | 32,227 | | $ | 4,004 | |
Adjustments to reconcile net income/(loss) to net cash provided by operating activities: | | | | | | | | | | | |
(Gains) losses on commodity derivative contracts—net | | 11,348 | | (7,493 | ) | 15,287 | | (12,358 | ) | 3,939 | |
Net cash received (paid) for commodity derivative contracts not designated as hedging instruments | | (3,518 | ) | 2,429 | | (3,677 | ) | 3,240 | | (160 | ) |
Asset retirement accretion | | 250 | | 283 | | 547 | | 559 | | 297 | |
Depreciation, depletion, and amortization | | 16,484 | | 15,959 | | 31,697 | | 31,301 | | 15,213 | |
Share-based compensation, net of amounts capitalized to oil and gas properties | | 1,215 | | 930 | | 3,425 | | 4,267 | | 2,210 | |
Amortization of deferred financing costs | | 108 | | 89 | | 216 | | 169 | | 108 | |
Change in operating assets and liabilities: | | | | | | | | | | | |
Accounts receivable—oil and gas sales | | 144 | | 2,707 | | 1,437 | | 5,519 | | 1,293 | |
Accounts receivable—JIB and other | | (1,050 | ) | 2,152 | | (1,713 | ) | 1,310 | | (663 | ) |
Other current and noncurrent assets | | 996 | | 1,298 | | (754 | ) | 642 | | (1,750 | ) |
Accounts payable | | 3,768 | | (470 | ) | 2,301 | | 809 | | (1,467 | ) |
Accrued liabilities | | (1,052 | ) | (817 | ) | (1,921 | ) | (4,466 | ) | (869 | ) |
Other | | (6 | ) | (5 | ) | (14 | ) | (42 | ) | (8 | ) |
Net cash provided by operating activities | | $ | 27,145 | | $ | 30,804 | | $ | 49,292 | | $ | 63,177 | | $ | 22,147 | |
CASH FLOWS FROM INVESTING ACTIVITIES: | | | | | | | | | | | |
Investment in property and equipment | | $ | (34,085 | ) | $ | (28,261 | ) | $ | (65,843 | ) | $ | (54,369 | ) | $ | (31,758 | ) |
Proceeds from the sale of oil and gas properties | | 54,432 | | — | | 54,432 | | — | | — | |
Proceeds from the sale of oil and gas equipment | | 355 | | — | | 355 | | 1,350 | | — | |
Net cash provided by (used in) investing activities | | $ | 20,702 | | $ | (28,261 | ) | $ | (11,056 | ) | $ | (53,019 | ) | $ | (31,758 | ) |
CASH FLOWS FROM FINANCING ACTIVITIES: | | | | | | | | | | | |
Repayment of revolving credit facility | | (50,000 | ) | — | | $ | (100,000 | ) | $ | — | | $ | (50,000 | ) |
Deferred financing costs | | — | | (375 | ) | — | | (375 | ) | — | |
Repurchase of restricted stock for tax withholdings | | (19 | ) | (622 | ) | (478 | ) | (622 | ) | (459 | ) |
Net cash used in financing activities | | $ | (50,019 | ) | $ | (997 | ) | $ | (100,478 | ) | $ | (997 | ) | $ | (50,459 | ) |
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS | | $ | (2,172 | ) | $ | 1,546 | | $ | (62,242 | ) | $ | 9,161 | | $ | (60,070 | ) |
Cash and cash equivalents, beginning of period | | $ | 8,428 | | $ | 84,453 | | $ | 68,498 | | 76,838 | | $ | 68,498 | |
Cash and cash equivalents, end of period | | $ | 6,256 | | $ | 85,999 | | $ | 6,256 | | $ | 85,999 | | $ | 8,428 | |
| | | | | | | | | | | |
SUPPLEMENTAL INFORMATION: | | | | | | | | | | | |
Non-cash transactions — investments in property and equipment accrued — not paid | | $ | 23,219 | | $ | 17,055 | | $ | 23,219 | | $ | 17,055 | | $ | 18,508 | |
Cash paid for interest, net | | $ | 1,225 | | $ | 1,170 | | $ | 3,010 | | $ | 2,107 | | $ | 1,785 | |
MIDSTATES PETROLEUM COMPANY, INC.
SELECTED FINANCIAL AND OPERATING STATISTICS
| | For the Three Months
Ended June 30, | | For the Six Months
Ended June 30, | | For the Three Months
Ended March 31, | |
| | 2018 | | 2017 | | 2018 | | 2017 | | 2018 | |
Operating Data — Mississippian Lime: | | | | | | | | | | | |
Net production volumes: | | | | | | | | | | | |
Oil (Bbls/day) | | 4,833 | | 4,938 | | 4,699 | | 5,269 | | 4,564 | |
NGLs (Bbls/day) | | 3,995 | | 4,466 | | 3,821 | | 4,526 | | 3,644 | |
Natural gas (Mcf/day) | | 50,246 | | 53,246 | | 47,083 | | 54,653 | | 43,857 | |
Total oil equivalents (MBoe) | | 1,566 | | 1,663 | | 2,963 | | 3,422 | | 1,397 | |
Average daily production (Boe/day) | | 17,202 | | 18,278 | | 16,367 | | 18,905 | | 15,518 | |
Operating Data — Anadarko Basin: | | | | | | | | | | | |
Net production volumes: | | | | | | | | | | | |
Oil (Bbls/day) | | 1,110 | | 1,475 | | 1,168 | | 1,420 | | 1,207 | |
NGLs (Bbls/day) | | 946 | | 1,115 | | 1,017 | | 1,104 | | 1,065 | |
Natural gas (MMcf) | | 7,956 | | 9,735 | | 8,365 | | 9,565 | | 8,671 | |
Total oil equivalents (MBoe) | | 206 | | 383 | | 540 | | 745 | | 334 | |
Average daily production (Boe/day) | | 3,382 | | 4,212 | | 3,579 | | 4,118 | | 3,717 | |
Operating Data - Combined: | | | | | | | | | | | |
Net production volumes: | | | | | | | | | | | |
Oil (Bbls/day) | | 5,943 | | 6,413 | | 5,867 | | 6,689 | | 5,771 | |
NGLs (Bbls/day) | | 4,941 | | 5,581 | | 4,838 | | 5,630 | | 4,709 | |
Natural gas (Mcf/day) | | 58,202 | | 62,981 | | 55,448 | | 64,218 | | 52,528 | |
Total oil equivalents (MBoe) | | 1,772 | | 2,046 | | 3,503 | | 4,167 | | 1,731 | |
Average daily production (Boe/day) | | 20,584 | | 22,490 | | 19,946 | | 23,023 | | 19,235 | |
Average Sales Prices: | | | | | | | | | | | |
Oil, without realized derivatives (per Bbl) | | $ | 67.39 | | $ | 46.73 | | $ | 64.87 | | $ | 48.16 | | $ | 62.41 | |
Oil, with realized derivatives (per Bbl) | | $ | 59.95 | | $ | 49.88 | | $ | 59.76 | | $ | 50.08 | | $ | 59.57 | |
Natural gas liquids, without realized derivatives (per Bbl) | | $ | 28.24 | | $ | 19.16 | | $ | 27.13 | | $ | 20.53 | | $ | 26.04 | |
Natural gas liquids, with realized derivatives (per Bbl) | | $ | 28.24 | | $ | 19.16 | | $ | 27.13 | | $ | 20.53 | | $ | 26.04 | |
Natural gas, without realized derivatives (per Mcf) | | $ | 1.34 | | $ | 2.66 | | $ | 1.55 | | $ | 2.78 | | $ | 1.76 | |
Natural gas, with realized derivatives (per Mcf) | | $ | 1.39 | | $ | 2.76 | | $ | 1.71 | | $ | 2.86 | | $ | 2.04 | |
Costs and Expenses (per Boe of production): | | | | | | | | | | | |
Lease operating | | $ | 6.45 | | $ | 7.12 | | $ | 6.63 | | $ | 6.63 | | $ | 6.83 | |
Workover | | $ | 3.12 | | $ | 0.97 | | $ | 2.44 | | $ | 1.15 | | $ | 1.73 | |
Gathering and transportation | | $ | 0.04 | | $ | 1.78 | | $ | 0.04 | | $ | 1.76 | | $ | 0.03 | |
Severance and other taxes | | $ | 1.57 | | $ | 0.83 | | $ | 1.61 | | $ | 0.92 | | $ | 1.65 | |
Asset retirement accretion | | $ | 0.14 | | $ | 0.14 | | $ | 0.16 | | $ | 0.13 | | $ | 0.17 | |
Depreciation, depletion and amortization | | $ | 9.30 | | $ | 7.80 | | $ | 9.05 | | $ | 7.51 | | $ | 8.79 | |
General and administrative | | $ | 2.93 | | $ | 3.70 | | $ | 4.30 | | $ | 3.80 | | $ | 5.70 | |
Advisory fees | | $ | 0.48 | | — | | $ | 0.24 | | — | | — | |
MIDSTATES PETROLEUM COMPANY, INC.
ADJUSTED EBITDA
(In thousands)
(Unaudited)
| | For the Three Months
Ended June 30, | | For the Six Months
Ended June 30, | | For the Three
Months Ended
March 31, | |
| | 2018 | | 2017 | | 2018 | | 2017 | | 2018 | |
Adjusted EBITDA to net income (loss) reconciliation: | | | | | | | | | | | |
Net income (loss) | | $ | (1,542 | ) | $ | 13,742 | | $ | 2,461 | | $ | 32,227 | | $ | 4,004 | |
Depreciation, depletion and amortization | | 16,484 | | 15,959 | | 31,697 | | 31,301 | | 15,213 | |
Losses (gains) on commodity derivative contracts—net | | 11,348 | | (7,493 | ) | 15,287 | | (12,358 | ) | 3,939 | |
Net cash received (paid) for commodity derivative contracts not designated as hedging instruments | | (3,518 | ) | 2,429 | | (3,677 | ) | 3,240 | | (160 | ) |
Income tax expense | | — | | — | | — | | — | | — | |
Interest income | | (5 | ) | — | | (24 | ) | — | | (19 | ) |
Interest expense, net of amounts capitalized | | 1,302 | | 1,228 | | 3,129 | | 2,205 | | 1,827 | |
Asset retirement obligation accretion | | 250 | | 283 | | 547 | | 559 | | 297 | |
Share-based compensation, net of amounts capitalized | | 1,215 | | 930 | | 3,425 | | 4,267 | | 2,210 | |
Adjusted EBITDA | | $ | 25,534 | | $ | 27,078 | | $ | 52,845 | | $ | 61,441 | | $ | 27,311 | |
Lagging costs associated with restructuring | | 298 | | 2,034 | | 335 | | 2,591 | | 37 | |
Costs incurred for strategic reviews | | 312 | | — | | 2,633 | | — | | 2,321 | |
Advisory costs | | 850 | | — | | 850 | | — | | — | |
Adjusted EBITDA before restructuring and advisory costs | | $ | 26,994 | | $ | 29,112 | | $ | 56,663 | | $ | 64,032 | | $ | 29,669 | |
MIDSTATES PETROLEUM COMPANY, INC.
CASH OPERATING EXPENSES
(In thousands)
(Unaudited)
| | For the Three Months
Ended June 30, | | For the Six Months
Ended June 30, | | For the Three
Months Ended
March 31, | |
| | 2018 | | 2017 | | 2018 | | 2017 | | 2018 | |
| | | | | | | | | | | |
Operating Expenses – GAAP | | $ | 42,569 | | $ | 45,709 | | $ | 85,662 | | $ | 91,262 | | $ | 43,093 | |
Adjustments for certain non-cash items: | | | | | | | | | | | |
Asset retirement accretion | | 250 | | 283 | | 547 | | 559 | | 297 | |
Share-based compensation, net | | 1,215 | | 930 | | 3,425 | | 4,267 | | 2,210 | |
Depreciation, depletion and amortization | | 16,484 | | 15,959 | | 31,697 | | 31,301 | | 15,213 | |
Cash Operating Expenses – Non-GAAP | | $ | 24,620 | | $ | 28,537 | | $ | 49,993 | | $ | 55,135 | | $ | 25,373 | |
Cash Operating Expenses – Non-GAAP per BOE | | $ | 13.89 | | $ | 13.94 | | $ | 14.27 | | $ | 13.23 | | $ | 14.66 | |
| | | | | | | | | | | |
Advisory fees | | $ | 850 | | $ | — | | $ | 850 | | $ | — | | $ | — | |
Advisory fees, per BOE | | $ | 0.48 | | $ | — | | $ | 0.24 | | $ | — | | $ | — | |
| | | | | | | | | | | |
Lagging costs associated with restructuring | | $ | 298 | | $ | 2,034 | | $ | 335 | | $ | 2,591 | | $ | 37 | |
Lagging costs associated with restructuring, per BOE | | $ | 0.17 | | $ | 0.99 | | $ | 0.10 | | $ | 0.62 | | $ | 0.02 | |
| | | | | | | | | | | |
Severance costs | | $ | 25 | | $ | — | | $ | 1,621 | | $ | — | | $ | 1,596 | |
Severance costs, per BOE | | $ | 0.01 | | $ | — | | $ | 0.46 | | $ | — | | $ | 0.92 | |
| | | | | | | | | | | |
Costs incurred for strategic reviews | | $ | 312 | | $ | — | | $ | 2,633 | | $ | — | | $ | 2,321 | |
Costs incurred for strategic reviews, per BOE | | $ | 0.18 | | $ | — | | $ | 0.75 | | $ | — | | $ | 1.34 | |
| | | | | | | | | | | |
Adjusted Cash Operating Expenses – Non-GAAP | | $ | 23,135 | | $ | 26,503 | | $ | 44,554 | | $ | 52,544 | | $ | 21,419 | |
Adjusted Cash Operating Expenses – Non-GAAP per BOE | | $ | 13.05 | | $ | 12.95 | | $ | 12.72 | | $ | 12.61 | | $ | 12.37 | |
MIDSTATES PETROLEUM COMPANY, INC.
ADJUSTED CASH GENERAL AND ADMINISTRATIVE EXPENSES
(In thousands)
(Unaudited)
| | For the Three Months
Ended June 30, | | For the Six Months
Ended June 30, | | For the Three
Months Ended
March 31, | |
| | 2018 | | 2017 | | 2018 | | 2017 | | 2018 | |
| | | | | | | | | | | |
General and Administrative Expenses – GAAP | | $ | 5,190 | | $ | 7,572 | | $ | 15,047 | | $ | 15,847 | | $ | 9,857 | |
Adjustments for certain non-cash and non-recurring items: | | | | | | | | | | | |
Share-based compensation, net | | (1,215 | ) | (930 | ) | (3,425 | ) | (4,267 | ) | (2,210 | ) |
Capitalized general and administrative expenses | | 636 | | 893 | | 1,299 | | 1,766 | | 663 | |
Severance costs | | (25 | ) | — | | (1,621 | ) | — | | (1,596 | ) |
Costs incurred for strategic reviews | | (312 | ) | — | | (2,633 | ) | — | | (2,321 | ) |
Lagging costs associated with restructuring included in general and administrative expenses | | (298 | ) | (2,034 | ) | (335 | ) | (2,591 | ) | (37 | ) |
Adjusted Cash General and Administrative Expenses – Non-GAAP | | $ | 3,976 | | $ | 5,501 | | $ | 8,332 | | $ | 10,755 | | $ | 4,356 | |
Adjusted Cash General and Administrative Expenses – Non-GAAP per BOE | | $ | 2.24 | | $ | 2.69 | | $ | 2.38 | | $ | 2.58 | | $ | 2.52 | |
