MIDSTATES PETROLEUM COMPANY, INC. Cowen and Company 4 th Annual - - PowerPoint PPT Presentation

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MIDSTATES PETROLEUM COMPANY, INC. Cowen and Company 4 th Annual - - PowerPoint PPT Presentation

MIDSTATES PETROLEUM COMPANY, INC. Cowen and Company 4 th Annual Ultimate Energy Conference Dr. Peter Hill, Interim CEO December 3, 2014 Forward-Looking Statements This presentation contains forward-looking statements within the meaning of the


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Cowen and Company 4th Annual Ultimate Energy Conference

  • Dr. Peter Hill, Interim CEO

December 3, 2014

MIDSTATES PETROLEUM COMPANY, INC.

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Forward-Looking Statements

This presentation contains forward-looking statements within the meaning of the federal Securities laws. All statements included in this presentation,

  • ther than statements of historical fact, regarding the Company’s strategy, goals, future operations, financial position, estimated revenues and losses,

projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this presentation, the words ‘‘could,’’ ‘‘believe,’’ ‘‘anticipate,’’ ‘‘intend,’’ ‘‘estimate,’’ ‘‘expect,’’ ‘‘may,’’ ‘‘continue,’’ ‘‘predict,’’ ‘‘potential,’’ ‘‘project,’’ “guidance,” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. 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 presentation are reasonable, the Company gives no assurance that actual future results will not differ materially from those forecasted in this

  • presentation. Moreover, such statements are subject to a number of assumptions, risks and uncertainties, 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. Each investor must assess and bear the risk of uncertainty inherent in the forward looking statements in this presentation. The Company discloses important factors that could cause its actual results to differ materially from its expectations in the “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” sections of the Company’s Form 10-K for the year ended December 31, 2013, and Form 10-Q for the quarters ended March 31,2014, June 30,2014, and September 30,2014 each filed with the Securities and Exchange Commission (“SEC”); and its other filings with the SEC. These factors include risks or liabilities assumed as a result of acquisitions, increases in our indebtedness, ability to complete any divestitures or other strategic transactions, ability to meet financial and operating guidance, ability to achieve production targets, successfully manage capital expenditures, and to complete and to test and produce the wells and prospects identified in this presentation; risks related to variations in the market demand for, and prices of, oil and natural gas; uncertainties related to commodity prices, uncertainties about the Company’s estimated quantities of oil and natural gas reserves or potential locations; infrastructure for salt water disposal and electricity; the adequacy of the Company’s capital resources and liquidity including, but not limited to, access to additional borrowing capacity under its revolving credit facility; general economic and business conditions; 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; pending litigation; and potential financial losses or earnings reductions from the Company’s commodity derivative positions. Accordingly, you should not place undue reliance on any of the Company’s forward-looking statements. All forward-looking statements speak only as

  • f the date on which such statements are 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.

NYSE: MPO | www.MidstatesPetroleum.com 2

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Reserve and Non-GAAP Information

This presentation also includes financial measures that are not in accordance with generally accepted accounting principles (“GAAP”), including Adjusted EBITDA and Cash Operating Expense. While management believes such measures are useful for investors because they allow for greater transparency with respect to key financial metrics, they should not be used as a replacement for financial measures that are in accordance with GAAP. The SEC permits oil and gas companies, in their filings with the SEC, to disclose proved reserves, which are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. SEC rules also permit the disclosure of “probable” and “possible” reserves. We disclose proved reserves but do not disclose probable or possible reserves. We may use certain broader terms such as “EUR” (as defined below) and other descriptions

  • f volumes of potentially recoverable hydrocarbon resources throughout this presentation that the SEC does not permit to be included in SEC filings.

These broader classifications do not constitute "reserves" as defined by the SEC, and we do not attempt to distinguish these classifications from probable or possible reserves as defined by SEC guidelines. We define EUR as the cumulative oil and gas production expected to be economically recovered from a reservoir or individual well from initial production until the end of its useful life. Our estimates of EURs and resource potential have been prepared internally by our engineers and management without review by independent engineers. These estimates are, by their nature, more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of being actually realized. We include these estimates to demonstrate what we believe to be the potential for future drilling and production by the Company. Actual locations drilled and quantities that may be ultimately recovered from our properties could differ substantially. In addition, we have made no commitment to drill all of the drilling locations which have been attributed to these quantities. Ultimate recoveries will be dependent upon numerous factors including actual encountered geological conditions, the impact of future oil and gas pricing, exploration and development costs, and future drilling decisions and budgets based upon our future evaluation of risk, returns and the availability of capital and, in many areas, the outcome of negotiation of drilling arrangements with holders of adjacent or fractional interest leases. Estimates of resource potential and other figures may change significantly as development of our properties provides additional data. Our forecast and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells, the undertaking and outcome of future drilling activity and activity that may be affected by significant commodity price declines or drilling cost increases. The Company’s estimates of total proved reserves at December 31, 2013 are based on reports provided by Netherland, Sewell & Associates, Inc. and Cawley, Gillespie & Associates, Inc., independent petroleum engineers.

NYSE: MPO | www.MidstatesPetroleum.com 3

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Refocused Energy

NYSE: MPO | www.MidstatesPetroleum.com 4

Deliver Financial Stability

Balance 2014 Operating Capex with Adjusted EBITDA $500-550MM Assure Liquidity Through 2015 to Fund Current Program Target Cash Flow Breakeven by 2016 Evaluate All Options to Improve Balance Sheet & Unlock Value

Exercise Capital Discipline

Focus on Miss Lime & Anadarko Control Costs & Expand Cash Margins High-Grade & Expand Inventory Allocate Rigs Where Returns are Highest

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2015 Strategic Direction and Intent

I. Release the Value in the Asset Base

  • Continue and enhance the value growth of the Miss Lime
  • Evaluate, pace and execute value growth in the Anadarko

II. Deliver the 2015 Budget and Work Program

  • Protect and improve liquidity where possible
  • Preliminary capital program of $450 - $475 million
  • Estimated Adjusted EBITDA at current strip prices of $475 - $500 million, with

hedging benefit

  • III. De-Lever the Balance Sheet
  • Continue to lower Net Debt/Adjusted EBITDA, with a goal of 2.5 – 3.0x
  • Monetize assets, continue to look at mergers/JV’s to accelerate stakeholder value
  • IV. Continue to Exercise Ruthless Capital Discipline
  • Reduce drilling and completion costs to maximize returns

NYSE: MPO | www.MidstatesPetroleum.com 5

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Oil 33% Gas 41% NGLs 26% Oil 40% Gas 38% NGLs 22%

Anadarko Basin

  • Multi-zone inventory yielding strong Hz results
  • 37 MMBoe proved reserves (67% liquids)(2)
  • 150-250 MMBoe net resource potential
  • Over 1,400 potential locations
  • 131,500 net acres (100,500 in TX and 31,000 in OK)
  • Q3 2014 net production: 8.4 MBoed

Gulf Coast (Fleetwood)

  • All producing properties planned to be

sold by 12/31/14

  • 20-60 MMBoe net resource potential
  • Over 140 potential locations
  • Future value from 3-D exploration

prospects to be initially funded by JV partner

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Gulf Coast ~1% Miss Lime ~72% Anadarko ~26%

2014E Capex By Area

Balanced Commodity Mix

Midstates Petroleum Overview

Midstates has a robust, strategically-located portfolio offering significant growth

Mississippian Lime(1)

  • Premier position in high-return core
  • 68 MMBoe proved reserves (57% liquids)(2)
  • 325-375 MMBoe net resource potential
  • Over 1,700 potential locations
  • 90,400 net acres, including 12,900 in

Lincoln County

  • Q3 2014 net production: 23.8 MBoed

NYSE: MPO | www.MidstatesPetroleum.com

(1) Includes Hunton acreage and reserves (2) Year end 2013 reserves prepared by NSAI in the Mississippian and Cawley Gillespie in the Anadarko

111 MMBoe

  • Liquids-weighted commodity mix with gas optionality

Growing Resource Base in Diverse Portfolio

Balanced growth – both through the drillbit and with strategic acquisitions Proved Reserves – YE2013 Net Resource Potential Reserves Growth

550-650 MMBoe

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High-Growth Resource and Well Inventory

NYSE: MPO | www.MidstatesPetroleum.com 7

  • Mid-Con activity to date has been focused
  • n the Upper Miss, Cleveland, Marmaton,

Tonkawa and Cottage Grove formations

  • High-quality inventory of low-risk horizontal

development from Upper Miss and proven Anadarko Basin plays

  • Significant upside exists from deep inventory
  • f locations, downspacing and emerging new

plays from multi-stacked horizons with compelling economics

  • Further upside expected from type curve

improvements

Company anticipates significant reserves growth through additional horizons, downspacing and well performance enhancements from completion and operational improvements

Overview Gross Undeveloped Locations Net Undeveloped Resource Potential: 550-650MMBoe

(1)

577 344 794 1,715 788 623 1,411 142 142 3,268 500 1,000 1,500 2,000 2,500 3,000 3,500

Upper Miss Upper Miss Downspacing

  • W. Anadarko

Base Additional Horizons Fleetwood Total Locations

Gross Well Locations

325 - 375 150 - 250 20-60

Miss Anadarko Fleetwood

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Focus on High Rates of Return

NYSE: MPO | www.MidstatesPetroleum.com 8

Robust economics even in challenged commodity price environments

Upper Miss IRRs at Various Prices Single Well Economics and Detail Anadarko IRRs at Various Prices

(1)

Key Economic Parameters Upper Miss Altered Upper Miss Enhanced Upper Miss Grainstone Cleveland Marmaton Tonkawa Cottage Grove Gross 24-hr IP, 2-stream (boepd) 750 1083 658 398 452 593 435 Gross EUR, 2-stream (MBoe) 520 527 471 203 221 283 309 % Liquids 56% 60% 63% 62% 67% 73% 79% D,C&F Cost ($mm) $3.8 $3.8 $3.8 $2.9 $3.2 $3.9 $4.0 F&D Cost, ($/Boe) $8.18 $8.14 $9.19 $15.61 $15.94 $15.15 $14.38 BT NPV-10 ($mm) (@$80/$4) $5.5 $5.7 $4.9 $1.5 $1.7 $3.1 $2.8 Locations 225 72 280 264 78 208 238

Note: Anadarko Basin economics run using best well costs by formation

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MPO Acreage Sandridge Acreage

KANSAS OKLAHOMA

Woods Alfalfa Grant Woodward Garfield Major

PETRA 8/13/2014 11:22:10 AM

Prolific Position in Recognized Core of Miss Lime

  • Highly contiguous 77,500 net acreage position in Woods and

Alfalfa Counties, which are largely HBP, in the recognized core of the play

  • Record high production in 3Q ’14 of 23,834 Boe/d
  • LOE/Boe (2) at record low of $3.36/Boe 3Q ’14
  • ~900 potential upper Miss locations with estimated net

resource potential of ~225 MMBoe

  • Evaluating ~700 additional potential locations in other

prospective horizons on our acreage with estimated net resource potential of ~125 MMBoe

(1) Includes Hunton Play in Lincoln County, OK (2) Includes workover expense

NYSE: MPO | www.MidstatesPetroleum.com 9

Chesapeake Acreage

Woods Alfalfa

PETRA 8/13/2014 11:14:49 AM

7,207 9,468 10,426 14,364 17,579 16,381 20,698 23,834

  • 5,000

10,000 15,000 20,000 25,000 30,000 Q4 2012 Q1 2013 Q2 2013 Q3 2013 Q4 2013 Q1 2014 Q2 2014 Q3 2014 Q4 2014E Gas NGL Oil

Net Production (Boe/d) (1)

24,000 – 25,000

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Unlocking Mississippian Lime Upside

Manning Updip limit Top “St. Gene.” Updip Limit Base “St. Gene.” Updip Limit

Primary Porosity Highly Altered

Middle Miss

Individual Depositional Porosity Intervals

Enhanced Porosity

  • Utilizing 3D Seismic

– High-graded locations – Optimized well placement and completion techniques – Opportunistically expanded acreage position

  • Future Potential

– Additional downspacing and multi-lateral potential – Stacked pay zones – Multiple Mississippian benches, other horizons in addition to the Miss

NYSE: MPO | www.MidstatesPetroleum.com 10

3D seismic and application of new technologies are considerably expanding the inventory of the Mississippian section

SSW NNE

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Grainstone Comparison Pre and Post Seismic

Across Two sections

  • Total of 23 wells D&C &
  • nline pre-seismic (~2011-

6/2013)

  • Total of 41 wells (&

counting) D&C & online post-seismic (6/2013- present) Major differences:

  • Longer lateral lengths
  • Stay in pay longer
  • Tailored Completion (frac

design)

  • Similar IP; differing EUR’s

NYSE: MPO | www.MidstatesPetroleum.com 11

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Mississippian Lime Future Development

  • Since Acquisition
  • Initially developed with four laterals per section –

1320’ well spacing

  • 3-D allows mapping of porosity units
  • See multiple layers of porosity
  • Geo-steered in porosity
  • Potential for Downspacing
  • Seen little/no well interference on 1320’ well spacing
  • Testing seven wells per section – 660’ well spacing
  • Confirmed with model analysis and OOIP map
  • Alternating Porosity intervals through sections
  • Spudding 5H downspacing location Q4’14

NYSE: MPO | www.MidstatesPetroleum.com 12

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Mississippian Lime: Differentiated Performance

  • Continuing Top Tier overall well performance in the Mississippian Lime
  • 189 wells on production >30 days: Average peak 30-day rate of 575 Boe/d
  • Four wells in Q3’14 with 30-day peak rates >1,000 Boe/d
  • With 3D seismic and improved geological understanding, 2014 well results skew to the high end

Peak 30-Day Production Rates through October 2014

Nearly 50% of all wells are >500 Boe/d; for those wells, IRRs are ~80% at 11/3/14 strip pricing

NYSE: MPO | www.MidstatesPetroleum.com 13

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Mississippian Lime D&C Performance Improvement

NYSE: MPO | www.MidstatesPetroleum.com 14

$4.5 $3.5 $3.6 $3.6 $3.7 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 Q3 2013 Q4 2013 Q1 2014 Q2 2014 Q3 2014

Well Cost $MM

  • Achieved Efficiency Improvements

– Pad drilling up to 6 wells per pad and re-built mud systems – Eliminated tank rentals and trucking and switched to 100% produced water for fracs

  • Anticipated Efficiency Improvements

– Frac design: use most cost-effective design by well – Potential service cost reductions due to soft macro environment estimated at 5% - 15%

Sandridge Average Lateral: $2.9mm

Q3 Results Midstates Sandridge Wells Online 20 122 D&C Cost $3.7mm $2.9mm 21% higher Avg 30 day peak rates(1) 660 368 79% higher Liquids Percentage 60% 52% 8% higher

Midstates Miss Target: $3.2mm

Focused on continuous improvements to maximize returns

(1) Rate is for Q3 wells only, MPO rate for all Miss wells is 575boe/d, SD is ~425boepd

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Mississippian Lime Stacked Horizontal Inventory

NYSE: MPO | www.MidstatesPetroleum.com 15

Acreage position overlays stacked pay zones which provide additional upside potential

Zone Future Gross Locations Estimated Net Resource (MMBoe) D&C ($mm) Upper Miss 577 125-150 $3.5-3.7 Upper Miss Downspacing 344 70-80 $3.5-3.7 Middle & Lower Miss 111 20-25 $4.0 (1) Viola 138 20-25 $3.6 (1) Woodford 68 5-10 $4.2 (1) Hunton 57 10-15 $2.5 (1) Cherokee (Red Fork) 83 15-20 $2.1 (1) Marmaton (Oswego) 143 30-40 $3.2 (1) Cottage Grove 96 15-20 $2.0 (1) Chester 98 10-15 $3.6 (1) Total 1,715 325-375

Oil Zone Gas Zone (1) Projected D&C costs

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Miss Lime Key Messages

NYSE: MPO | www.MidstatesPetroleum.com 16

  • Best Results in the Miss Lime
  • Average 30 day peak rates 575 Boe/d
  • Type curve 2 stream EURs 470-530 MBOE
  • LOE/Boe of $3.36/Boe
  • Geological understanding and technical expertise help to differentiate our results
  • Reservoir modeling conclusions show downspacing needed to fully drain reservoir in certain areas
  • Downspacing testing currently underway
  • Stacked Horizon inventory beyond upper Miss of ~800 locations
  • Tremendous well level economics (80% at $80 oil) allows for profitability in a low price environment

MPO differentiated results driven by premium acreage and our understanding of the geology

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MPO Apache

  • Strong acreage position, gaining and leveraging knowledge
  • Solid, repeatable results in the de-risked Cleveland with encouraging early results in other horizons
  • Sands are not uniform; drilling thickest, most permeable areas is critical to generate highest return wells
  • Upside locations exist in multiple formations which have been horizontally drilled by other companies

Anadarko Basin: Liquids-Rich Targets

NYSE: MPO | www.MidstatesPetroleum.com

OKLAHOMA TEXAS

Beaver Harper Woods Woodward Ellis Dewey Roger Mills Custer Ochiltree sford Lipscomb Roberts Hemphill inson

PETRA 8/13/2014 11:05:55 AM

Jones Sandridge Chesapeake

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Anadarko Basin Well Cost Performance

NYSE: MPO | www.MidstatesPetroleum.com 18

$3.4 $3.8 $4.2 $4.1 $2.9 $3.2 $4.0 $3.9 0.0 1.0 2.0 3.0 4.0 5.0 Cleveland Marmaton Cottage Grove Tonkawa

Well Cost $MM

Historical Average* Best Well

  • Cleveland and Marmaton

– Consistent cost performance – Majority of drilling activity since acquisition – Significant cost performance improvement since acquisition

  • Cottage Grove and Tonkawa

– Limited activity since acquisition – Opportunity to apply learnings from other horizons to realize efficiency gains

32 Wells 10 Wells 7 Wells 3 Wells

Focused on well cost improvements consistent with successful improvements in the Mississippian Lime

*Historical Average: Excludes wells with major mechanical issues

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Anadarko Basin Type Curves Capital Sensitivity (1)

AVG BEST AVG BEST AVG BEST AVG BEST (1) At $80 WTI & $4.00 HH

NYSE: MPO | www.MidstatesPetroleum.com 19

Lowering D&C costs can significantly improve returns at any commodity price

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Anadarko Basin Stacked Horizontal Inventory

NYSE: MPO | www.MidstatesPetroleum.com 20

Zone Future Gross Locations Estimated Net Resource (MMBoe) D&C ($mm) Cleveland 264 25-35 $3.4 Marmaton 78 10-15 $3.8 Tonkawa 208 20-30 $4.1 Cottage Grove 238 20-30 $4.2 Atoka (Oil) 94 5-10 $3.6 (1) Atoka (Gas) 22 2-5 $3.6 (1) Oswego (Upper) 142 25-50 $3.7 (1) Oswego (Lower) 181 30-60 $3.7 (1) Other (2) 184 15-25 $2.0-$3.5 (1) Total 1,411 150-250

Oil Zone Gas Zone (1) Projected D&C costs (2) “Other” includes Douglas, Kansas City, Red Fork and Morrow

Acreage position overlays stacked pay zones which provide additional upside potential

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  • Consistent results in the Cleveland, with encouraging early results in the other horizons
  • Expanding geological understanding and high grading locations
  • Optimizing drilling and completion designs to lower costs and improve well deliverability and returns
  • Opportunities to learn from other operators
  • Stacked Horizon inventory beyond Cleveland, Marmaton, Tonkawa & Cottage Grove of ~600 locations
  • Primary horizons demonstrate predictable results and provide attractive returns with acheivable cost

reductions or more favorable commodity prices

Anadarko Key Messages

NYSE: MPO | www.MidstatesPetroleum.com 21

Learnings from the Miss Lime, stacked pay potential, and new D&C techniques will drive improvements

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Fleetwood 3D Seismic Area: Organic Growth Potential

  • Fleetwood 3D Survey: 197 Sq. Miles
  • ~15,000 Net Acres post PetroQuest Farmout
  • 12 Identified Leads/Prospects

– Gross Resource Potential: 191 MMBOE (Mean); 557 MMBOE (P10)

  • Fleetwood Farm-out with PetroQuest executed 6/25/14

– $10mm cash consideration, $14mm future carry – PetroQuest will operate all but one prospect

  • 4 wells planned from July 2014 - July 2015

– 2014 wells: Bayou Cholpe (Lower Wilcox) Spudding in Q4 – 2015 wells: Konik (Cockfield) Likely Spudding early Q1 and TBD (Big Red Stick West & Lower Rowe)

  • MPO Interest Going Forward

– Kenmore AMI (Konik/Maringouin): MPO 25% (50% Vitol group; 25% PQ) – Bayou Cholpe: MPO 25% (50% Vitol; 25% PQ) – Remainder of Inventory: MPO 50%, PQ 50%

Fleetwood Overview

22 NYSE: MPO | www.MidstatesPetroleum.com

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Miss Miss Miss Anadarko Anadarko Gulf Coast Gulf Coast Gulf Coast 9,999 23,926 32,000-35,000

  • 5,000

10,000 15,000 20,000 25,000 30,000 35,000 40,000 2012 2013 2014E

Boed

Midstates Financial Performance

NYSE: MPO | www.MidstatesPetroleum.com 23

$145 $330

100 200 300 400 500 2012 2013 2014E

$MM

Q2 $114 Q3 $132 Q2 $123

Market understates Midstates’ performance and progress allowing for an attractive investment opportunity

Production Growth over Time Balancing Operational Capex with Adjusted EBITDA $102 $119 $114 $123 $132 $160 $135 $135 $141 $134 $- $50 $100 $150 $200 Q3'13 Q4'13 Q1'14 Q2'14 Q3'14 EBITDA OP CAPEX Adjusted EBITDA Growth over Time

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$42.35 $34.96 $32.75 $20.00 $25.00 $30.00 $35.00 $40.00 $45.00 MPO Peer 1 Peer 2

Operating Margin Improvements

(1) See reconciliation in the appendix (2) Peers include Sandridge and Jones, Q3 data used where available, if unavailable Q2 data used

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Quarterly Adjusted EBITDA(1) / Boe

  • Adjusted EBITDA enhanced by strong well

performance, focus on liquids rich areas and aggressive operating cost management

  • EBITDA/Boe exceeds peer group due to low

costs and strong Miss Lime results

  • Operating costs in Miss Lime have fallen to

$3.36/Boe

  • 20% Reduction in Miss Lime absolute costs

from Q3 2013 to Q3 2014

  • Operating cost management helps mitigate

macro pricing weakness

  • LOE and G&A improvements are sustainable,

with potential for continued improvement Q3 2014 EBITDA / Boe vs. Mid Con Peer Group(2)

$39.04 $41.35 $43.71 $42.26 $42.35 $20.00 $25.00 $30.00 $35.00 $40.00 $45.00 Q3 2013 Q4 2013 Q1 2014 Q2 2014 Q3 2014

NYSE: MPO | www.MidstatesPetroleum.com

$8.32 $7.04 $7.71 $6.79 $5.46 $4.58 $4.27 $3.89 $3.90 $2.63 $3.09 $2.31 $2.93 $1.94 $1.86 $1.09 $1.01 $1.26 $16.98 $14.61 $15.62 $13.63 $11.21 $0.00 $2.00 $4.00 $6.00 $8.00 $10.00 $12.00 $14.00 $16.00 $18.00 Q3 2013 Q4 2013 Q1 2014 Q2 2014 Q3 2014 $/BOE Gathering & Transportation Severance & Other Taxes G&A (Cash) OpEx

Cash Operating Expense Improvements Over Time (1)

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Sustaining Positive Momentum Into 2015 & Beyond

RAMP UP

Production: 35,000 – 36,000 BOEPD Capital: $475 mm - $525 mm

  • Adj. EBITDA: $525 mm - $600 mm

Rigs: 7-8 Miss, 2-3 Anadarko

Free Cash Flow 1H2016 BASE PLAN

Production: 34,000 – 35,000 BOEPD Capital: $450 mm - $475 mm

  • Adj. EBITDA: $475 mm - $525 mm

Rigs: 7 Miss, 1-2 Anadarko

Free Cash Flow Late 2016 SLOW DOWN

Production: 33,000 – 34,000 BOEPD Capital: $400 mm - $450 mm

  • Adj. EBITDA: $450 mm - $475 mm

Rigs: 6-7 Miss, 0-1 Anadarko

Free Cash Flow 1H2017 2015 Preliminary Estimates

Base Oil Price $80 - $90 High Oil Price $90 - $100 Low Oil Price $70 - $80

NYSE: MPO | www.MidstatesPetroleum.com 25

Midstates is positioned to tackle the uncertain macro environment heading into 2015

2015 estimate: $1 change in oil price results in ~ $2.5mm change in Adjusted EBITDA

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Liquidity

$ millions

  • Liquidity @ September 30, 2014 : $181 mm
  • Projected Liquidity @ December 31, 2014 $160 mm - 180 mm
  • Improving debt metrics
  • Hedging portfolio through 2015 provides increased

predictability of cash flow

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Cash Balance Borrowing base Net Liquidity September 30 Liquidity $26,000 ($370,000) $525,000 $181,000 Revolver

4.4 4.1 4.0 3.6 0.0 1.0 2.0 3.0 4.0 5.0 YE'13 Q1'14 Q2'14 Q3'14

Net Debt / Adjusted EBITDA

Potential Actions to Further Improve Liquidity:

  • Lincoln County Monetization
  • Primarily gas, with upside resource potential allowing us to

further focus on Miss Lime

  • Fleetwood Monetization
  • With Petroquest success, attractive and material valuations

could be possible allowing us to focus on our core Mid continent assets

  • Miss Lime Salt Water Disposal (SWD) System Monetization
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Attributes of Stand Alone Company

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  • Vast resource potential and large, high quality inventory of drilling locations
  • Strong production growth to 33,000 – 34,000 Boe/d heading into 2015
  • Adjusted EBITDA growth to nearly $500 million in 2014 was balanced with operating capex

by year end

  • Differentiated position in Miss Lime with strong potential for future growth
  • Knowledge gained in Miss Lime transferrable to Anadarko Basin
  • Ruthless capital discipline to maximize returns
  • Deliver financial stability to protect and expand liquidity and improve balance sheet and

debt metrics

Midstates has the flexibility, cost structure and asset base to withstand the current macro price uncertainty

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APPENDIX

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Illustrative Miss Lime Single Well Economics

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Solid repeatable results with compelling well economics; Midstates outperforming peers

Upper Miss Type Curves

Key Economic Parameters Altered Enhanced Grainstone Oil 24-hr IP (bpd) 400 575 350 Gas 24-hr IP (mcfd) 2,100 3,050 1,850 NGL Yield (bbl/Mmcf) 65 65 65 Gross EUR, 2-stream (MBoe) 520 527 471 D&C Cost ($mm) $3.8 $3.8 $3.8 F&D Cost, ($/Boe) $8.18 $8.14 $9.19 Gas Diff $ ($0.19) ($0.19) ($0.19) Oil Diff $ ($2.70) ($2.70) ($2.70) NGL as % of Oil Price 36% 36% 36%

IRR Sensitivity Type Curve Assumptions – Upper Miss

# of Locations Upper Miss Altered 225 Upper Miss Enhanced 72 Upper Miss Grainstone 280 Upper Miss Altered (Downspace) 83 Upper Miss Grainstone (Downspace) 261 Total (With Downspacing) 921

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Illustrative Cleveland Single Well Economics

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Low-risk portfolio ranging from mature to high-growth assets, with diverse product mix and competitive D&C capital requirements Cleveland Type Curve IRR Sensitivity Type Curve Assumptions – Cleveland

Key Economic Parameters Oil 24-hr IP (bpd) 203 Gas 24-hr IP (mcfd) 1,167 NGL Yield (bbl/Mmcf) 77 Gross EUR, 2-stream (MBoe) 203 D&C Cost ($mm) $2.9 - $3.4 F&D Cost, ($/Boe) $15.61 - $18.31 Gas Diff $ ($0.36) Oil Diff $ ($4.00) NGL as % of Oil Price 40%

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Illustrative Marmaton (Hepler) Single Well Economics

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Low-risk portfolio ranging from mature to high-growth assets, with diverse product mix and competitive D&C capital requirements Marmaton Type Curve Type Curve Assumptions – Marmaton

Key Economic Parameters Oil 24-hr IP (bpd) 315 Gas 24-hr IP (mcfd) 826 NGL Yield (bbl/Mmcf) 82 Gross EUR, 2-stream (MBoe) 221 D&C Cost ($mm) $3.2 - $3.8 F&D Cost, ($/Boe) $15.54 - $18.22 Gas Diff $ ($0.36) Oil Diff $ ($4.00) NGL as % of Oil Price 40%

IRR Sensitivity

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Illustrative Tonkawa Single Well Economics

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Low-risk portfolio ranging from mature to high-growth assets, with diverse product mix and competitive D&C capital requirements Tonkawa Type Curve Type Curve Assumptions – Tonkawa

Key Economic Parameters Oil 24-hr IP (bpd) 454 Gas 24-hr IP (mcfd) 836 NGL Yield (bbl/Mmcf) 92 Gross EUR, 2-stream (MBoe) 283 D&C Cost ($mm) $3.9 - $4.1 F&D Cost, ($/Boe) $15.15 - $15.92 Gas Diff $ ($0.36) Oil Diff $ ($4.00) NGL as % of Oil Price 40%

IRR Sensitivity

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Illustrative Cottage Grove Single Well Economics

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Low-risk portfolio ranging from mature to high-growth assets, with diverse product mix and competitive D&C capital requirements Cottage Grove Type Curve Type Curve Assumptions – Cottage Grove

Key Economic Parameters Oil 24-hr IP (bpd) 336 Gas 24-hr IP (mcfd) 594 NGL Yield (bbl/Mmcf) 103 Gross EUR, 2-stream (MBoe) 309 D&C Cost ($mm) $4.0 - $4.2 F&D Cost, ($/Boe) $14.38 - $15.10 Gas Diff $ ($0.36) Oil Diff $ ($4.00) NGL as % of Oil Price 40%

IRR Sensitivity

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D&C 90 - 95%

Land, Seismic, Infrastructure 5 - 10%

By Type

Operating Capital (1) First Glance: $450 to $475 million

  • Focused on Miss Lime which returns ~80% IRR at $80 oil
  • ~80-90% Miss Lime and 10-20% Anadarko
  • ~90-95% dedicated to Drilling and Completing

8 rigs planned in Q1 2015 with flexibility to ramp up or down

  • 7 rigs in the Miss Lime
  • 1 rigs in the Anadarko Basin

Capital Efficiency and Discipline

  • Drilling highest rate of return projects / areas
  • Acreage rationalization in Anadarko based on macro environment

Goal: Maintain 2015 Operating Capital Expenditures less than Adjusted EBITDA

2015 Capital Preview

Miss Lime 80-90% Anadarko 10-20%

By Area

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(1) Excludes capitalized interest and G&A, asset retirement obligations, office and other expenditures

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Salt Water Disposal System

  • System overview: Woods and Alfalfa counties

– 345-430 Mbwd of capacity permitted – Six high-capacity SWD wells within central loop and pipeline network of ~100 miles – Eight total SWD wells across Woods and Alfalfa allows for significant growth – Currently disposing ~170 Mbwd into the Arbuckle formation at minimal cost

  • Value Proposition

– Significant untapped third-party capacity potential – At a disposal charge of $0.50-$1/bbl and 5x-10x EBITDA, creates attractive value proposition – Opportunity to further enhance financial position

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Intrinsic value exists in Midstates’ existing infrastructure, which will grow with additional development

1 2 Miles

1:115,000

:

Date: 6/26/2014

Datum: WGS84 Projection: Mercator
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SWD Monetization Opportunity

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Bill WI Owners Add 3rd Party Monetization 50% utilized Monetization fully utilized

Value / Time Options

Time and effort creates substantial opportunity

Low High

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Hedging Summary (as of Nov 4, 2014) (3)

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Oil

Q4 Total Q1 Q2 Q3 Q4 Total WTI Swaps Volume (Bbls) 1,097,000 1,097,000 1,080,000 1,092,000 552,000 552,000 3,276,000 Volume (Bbl/d) 11,924 11,924 12,000 12,000 6,000 6,000 8,975 Price ($/Bbl) 89.04 $ 89.04 $ 90.10 $ 90.58 $ 85.51 $ 85.53 $ 88.72 $ WTI Collars Volume (Bbls) 40,200 40,200 Volume (Bbl/d) 437 437 Price ($/Bbl) - Floor 86.49 $ 86.49 $ Price ($/Bbl) - Ceiling 97.71 $ 97.71 $ WTI/LLS Basis Differential Swaps (1) Volume (Bbls) 91,500 91,500 Volume (Bbl/d) 995 995 Price ($/Bbl) 5.35 $ 5.35 $

Natural Gas Liquids

Swaps Volume (Bbls) Volume (Bbl/d) Price ($/Bbl)

Natural Gas

Swaps (2) Volume (Mmbtu) 4,508,000 4,508,000 4,500,000 4,550,000 4,600,000 4,600,000 18,250,000 Volume (Mmbtu/d) 49,000 49,000 50,000 50,000 50,000 50,000 50,000 Price ($/Mmbtu) $4.17 $4.17 $4.13 $4.13 $4.13 $4.13 $4.13 Collars Volume (Mmbtu) 194,001 194,001 Volume (Mmbtu/d) 2,109 2,109 Price ($/Mmbtu) - Floor 3.39 $ 3.39 $ Price ($/Mmbtu) - Ceiling 4.57 $ 4.57 $ 2014 2015

Natural Gas

Swaps (2) Volume (Mmbtu) 4,508,000 4,508,000 4,500,000 4,550,000 4,600,000 4,600,000 18,250,000 Volume (Mmbtu/d) 49,000 49,000 50,000 50,000 50,000 50,000 50,000 Price ($/Mmbtu) $4.17 $4.17 $4.13 $4.13 $4.13 $4.13 $4.13 Collars Volume (Mmbtu) 194,001 194,001 Volume (Mmbtu/d) 2,109 2,109 Price ($/Mmbtu) - Floor 3.39 $ 3.39 $ Price ($/Mmbtu) - Ceiling 4.57 $ 4.57 $

(1) The company enters into swap arrangements intended to fix the differential between the Louisiana Light Sweet (“LLS”) pricing and the West Texas Intermediate (“NYMEX WTI”) pricing. (2) Includes 1,519,000 Mmbtus in natural gas swaps that priced during the period, but had not cash settled as of September 30, 2014. (3) Includes new 3Q & 4Q 2015 oil hedges that were added in October 2014.

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Adjusted EBITDA Reconciliation

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For the Three Months Ended Sept 30, For the Three Months Ended June 30, For the Three Months Ended March 31, For the Year Ended December 31, 2014 2014 2014 2013 2012 2011 Adjusted EBITDA reconciliation to net income (loss): Net income (loss) 74,597 (2,098) (83,645) (343,985) (150,097) 16,657 Depreciation, depletion and amortization 73,109 71,074 66,901 250,396 125,561 91,699 Impairment in carrying value of oil and gas properties 86,471 453,310

  • Losses on commodity derivative contracts — net

(50,978) 31,467 22,673 44,284 11,158 4,844 Net cash (paid) received for commodity derivative contracts not designated as hedging instruments (7,265) (17,138) (14,810) (17,585) (15,825) (16,733) Income tax expense (benefit) 2,216 (41) (2,270) (146,529) 157,886

  • Interest income

(10) (9) (10) (33) (245) (23) Interest expense, net of amounts capitalized 34,288 33,813 33,947 83,138 12,999 2,094 Asset retirement oglibation accretion 406 432 497 1,435 723 334 Share-based compensation 1,690 2,127 1,541 5,713 2,459 53,744 Adjusted EBITDA 130,399 119,627 111,295 330,144 144,619 152,616 Acquisition and transaction costs 1,283 2,483 128 11,803 14,884 Adjusted EBITDA, before acquisition and transaction costs 131,682 122,110 111,423 341,947 159,503 152,616

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Cash Operating Expenses Reconciliation

2014 2013 Q3 Q2 Q1 Q1 Q2 Q3 Q4 Operating Expenses - GAAP $113,670 $ 116,325 $ 196,640 $ 73,082 $ 104,061 $ 122,376 $ 577,396 Adjustments for certain non-cash items: Asset retirement accretion (406) (432) (497) (254) (313) (421) (447) Share-based compensation, net of amounts capitalized (1,690) (2,127) (1,541) (1,244) (1,770) (1,908) (792) Depreciation, depletion, and amortization (73,109) (71,074) (66,901) (41,976) (52,830) (74,789) (80,801) Impairment on oil and gas properties (86,471)

  • -
  • (453,310)

Other (2,346) (609) (330)

  • -

(614) (1) Cash Operating Expenses - Non-GAAP (1) $ 36,119 $ 42,083 $ 40,900 $ 29,608 $ 49,148 $ 44,644 $ 42,045 Cash Operating Expenses - Non-GAAP, per Boe (1) $ 11.62 $ 14.49 $ 15.67 $ 20.29 $ 27.50 $ 17.05 $ 14.65 Acquisition and transaction costs per Boe $ 0.41 $ 0.86 $ 0.05 $ - $ 6.43 $ 0.07 $ 0.04

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Tranche Rating Amount ($mm) Coupon Maturity Date Trading Price YTW Call Dates Call Price Caa1 / CCC+ $600 10.75% October 1, 2020 90.75 13% 10/1/16 – 9/30/17 10/1/17 – 9/30/18 After 10/1/18 105.38 102.69 100.00 Caa1 / CCC+ $700 9.25% June 1, 2021 86.25 12.4% 6/1/16 – 5/30/17 6/1/17 – 5/30/18 6/1/18 – 5/30/19 After 6/1/19 106.94 104.63 102.31 100.00

Capitalization

NYSE: MPO | www.MidstatesPetroleum.com 40 Summary of MPO Bonds Capitalization

As of September 30, 2014 Cash and Equivalents $ 25.7 Debt RCF Borrowings $ 369.2 10.75% Senior Notes due 2020 $ 600.0 9.25% Senior Notes due 2021 $ 700.0 Total Debt $ 1,669.2 Shareholders' Equity $ 334.3 Total Capitalization $ 2,003.4 RCF Borrowing Base $ 525.0 Less: Borrowings (369.2) RCF Availability $ 155.9 Total Liquidity $ 181.6 Debt / 2014E EBITDA 3.4x Debt / Capitalization 83% Net Debt / 2014E EBITDA 3.4x Net Debt / Capitalization 83%

Liquidity Credit Metrics Capitalization

Net Debt / 2014E EBITDA 3.4x Net Debt / Capitalization 83%

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Preferred Share Dividend Calculation

Key Tems Dividend Payment dates: March 30 September 30 Rate: 8% per annum Compounding: Semi-annually Number of shares: 325,000 Initial liquidation preference: $ 1,000 per share Year: 360 days NYSE: MPO | www.MidstatesPetroleum.com 41

(a) Calculated assuming $13.50 conversion. (b) Calculated assuming $11.00 conversion. Includes $2,103,242 related to prior periods for change in conversion rate dividend valuation purposes.

Per share Total

Conversion into Common Shares @ $13.50 Conversion into Common Shares @ $11.00

Liquidation preference at October 1, 2012: 1,000.00 $ 325,000,000 $ 24,074,074 29,545,455 Dividend Amount at March 30, 2013: 40.00 $ 13,000,000 962,963 1,181,818 Liquidation preference at March 30, 2013: 1,040.00 $ 338,000,000 $ 25,037,037 30,727,273 Dividend amount at September 30, 2013: 41.60 $ 13,520,000 1,001,481 1,229,091 Adjusted liquidation preference at September 30, 2013: 1,081.60 $ 351,520,000 $ 26,038,519 31,956,364 Dividend amount at December 31, 2013: 21.63 $ 7,030,400 520,770 639,127 Adjusted liquidation preference at December 31, 2013: 1,103.23 $ 358,550,400 $ 26,559,289 32,595,491 Accrued dividend amount at March 30, 2014: 21.63 $ 7,030,400 520,770 639,127 Adjusted liquidation preference at March 30, 2014: 1,124.86 $ 365,580,800 $ 27,080,059 33,234,618 Accrued dividend amount at September 30, 2014: 44.99 $ 14,623,232 1,083,202 1,329,385 Adjusted liquidation preference at September 30, 2014: 1,169.86 $ 380,204,032 $ 28,163,262 34,564,003 Calculation

Conversion into Common Shares @ $11.00

Accumulated dividend amount at 9/30/14 14,623,232 Conversion price 11.00 $ Additional shares 1,329,385 Share price at September 30, 2014 5.05 $ Dividend amount as calculated 6,713,393 $ 2013: Reported Q1 Dividend Amount 4,116,667 $

(a)

Q2 Dividend Amount 2,568,800

(a)

Q3 Dividend Amount 2,568,800

(a)

Q4 Dividend Amount 6,334,265

(b)

Full year 2013 Dividend (assuming $11.00 conversion) 15,588,532 $ 2014: Q1 Dividend Amount 2,620,421 $ Q2 Dividend Amount 4,805,726 $ Q3 Dividend Amount 1,907,667 $ Third Quarter 2014

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Midstates Petroleum Company


HOUSTON 4400 Post Oak Pkwy, Suite 2600

Houston, TX 77027 Main Phone (713) 595-9400 Fax (713) 595-9499

TULSA

321 South Boston, Suite 600 Tulsa, Oklahoma 74103 Main Phone (918) 947-8550

Contact Information

Investor Relations Chris Delange

Investor Relations Manager (713) 595-9411 Chris.delange@midstatespetroleum.com

Al Petrie

Investor Relations, Coordinator (713) 595-9427 Al.petrie@midstatespetroleum.com

Investorrelations@midstatespetroleum.com Direct Line: (713) 595-9333 www.MidstatesPetroleum.com NYSE: MPO | www.MidstatesPetroleum.com 42