MIDSTATES PETROLEUM COMPANY, INC. Johnson Rice & Company Energy - - PowerPoint PPT Presentation

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MIDSTATES PETROLEUM COMPANY, INC. Johnson Rice & Company Energy - - PowerPoint PPT Presentation

MIDSTATES PETROLEUM COMPANY, INC. Johnson Rice & Company Energy Conference Nelson Haight, Senior VP and CFO September 29, 2014 Forward-Looking Statements This presentation contains forward-looking statements within the meaning of the


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SLIDE 1

Johnson Rice & Company Energy Conference Nelson Haight, Senior VP and CFO September 29, 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 quarter ended March 31,2014, and Form 10-Q for the second quarter ended June 30,2014, each filed with the Securities and Exchange Commission (“SEC”); and its other filings with the SEC. These factors include the Company's ability to integrate its Anadarko Basin acquisition and realize anticipated benefits therefrom, risks or liabilities assumed as a result of the acquisition, 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, uncertanties about the Company’s estimated quantities of oil and natural gas reserves, resource potential and drilling locations, 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 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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SLIDE 3

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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SLIDE 4

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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SLIDE 5

Midstates Petroleum Overview

Q2 2014 Avg Daily Production 31,912 Boe/d Oil (% Total) 14,290 Boe/d (45%) NGL (% Total) 6,609 Boe/d (21%) Proved Reserves Proforma @ 12/31/13 111 million BOE (3) Oil (% Total) 44.6 million Boe (40%) NGL (% Total) 23.9 million Boe (22%) Proved PV-10 Proforma @ 12/31/13 $1.7 B (3) 2014 Production Guidance 32,000 – 35,000 Boe/d 2014 Operational Capex/EBITDA Guidance $500mm - $550mm 2014 LOE/Boe Guidance $6.75 - $7.25 / Boe

  • Achieved Adjusted EBITDA(4) of $122mm in 2Q’14
  • July daily production grew to 33,300 Boe/d (5)
  • Reduced Cash Operating Expenses(4) by 13% Q on Q
  • Liquidity at June 30, 2014 ~$150mm; sufficient

liquidity to fund program through 2015

  • High grading inventory, continue to evaluate ~3,300

gross undeveloped locations, ~615 MMBoe net resource potential

Recent Accomplishments

Anadarko

131,500 net acres(2) ~215 MMBoe net resource potential with ~1,550 gross undeveloped locations

Mississippian Lime Area(1)

90,400 net acres(2) ~350 MMBoe net resource potential with ~1,600 gross undeveloped locations

Gulf Coast

45,700 net acres(6) ~50 MMBoe net resource potential with ~120 gross undeveloped locations Pursing sale of Dequincy properties NYSE: MPO | www.MidstatesPetroleum.com 5

(1) Includes Hunton acreage and reserves (2) Net acreage as of June 30, 2014 (3) Adjusted for Pine Prairie sale (4) See reconciliation in Appendix (5) Includes Dequincy production of ~1,600 boe/d (6) Net acreage as of June 30, 2014 adjusted for Fleetwood exploration agreement

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$153 $145 $330 100 200 300 400 500 2011 2012 2013 2014E $MM Q1 $111

$500-$550

Q2 $122

Growing Production and EBITDA

Demonstrated History of Growth

  • Organic F&D Costs: $13.59/Boe
  • Acquisition Costs: $16.48/Boe
  • All-in F&D & Acq Costs, including Revisions: $20.09/Boe, or $12.00/Boe excluding the Gulf Coast

Unrecognized Potential

  • Expect 2014 Adjusted EBITDA and Operating Capex(2) spend to each be between $500-$550MM
  • Current share price at a significant discount vs. peers on 2014 CF/share, EBITDA and production
  • Pro Forma Debt/LTM Adjusted EBITDA Multiple of 3.96x(3); projected to be reduced to 3.5x by year-end 2014

(1) See reconciliation in Appendix (2) Operating Capex excludes capitalized interest and G&A, asset retirement obligations, office and other expenditures (3) Calculated per the terms of the revolving credit facility which includes pro forma impact of Pine Prairie sale

Net Production Adjusted EBITDA(1)

Miss Miss Miss Miss Anadarko Anadarko Anadarko Gulf Coast Gulf Coast Gulf Coast Gulf Coast Gulf Coast 7,499 9,999 23,926 32,000 - 35,000 31,912

  • 5,000

10,000 15,000 20,000 25,000 30,000 35,000 40,000 2011 2012 2013 2Q 2014 2014E BOE/D

NYSE: MPO | www.MidstatesPetroleum.com 6

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SLIDE 7

MPO Acreage Sandridge Acreage

7,207 9,468 10,426 14,364 17,579 16,381 20,698 21,525

  • 5,000

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

Mississippian Lime: Premier Position

  • Premier position in the Miss Lime trend
  • Highest return wells in our portfolio
  • Record high production in July ~23,000 Boe/d
  • LOE/Boe (2) at record low of $4.51/Boe 2Q ’14
  • 900+ potential upper Miss locations (including potential

downspacing) across acreage, 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

Focus on Miss Lime & Anadarko

Net Production (Boe/d) (1)

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

21,000 – 23,000

NYSE: MPO | www.MidstatesPetroleum.com 7

Chesapeake Acreage

Woods Alfalfa

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Mississippian Lime: Quantifying the Upside

High-Grade & Expand Inventory

Utilizing 3D Seismic

  • High-grade locations
  • Optimize well placement and completion

techniques

  • Opportunistically expand acreage position

Future Potential

  • Additional downspacing & multi lateral potential
  • Stacked pay zones
  • Multiple Mississippian benches with additional

potential in other horizons

NYSE: MPO | www.MidstatesPetroleum.com 8

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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
  • “Proof of concept”
  • Multi-laterals
  • Open hole completions
  • Test multi-layers of porosity - 40-80’ apart
  • Higher EUR’s from section
  • Lower well cost

High-Grade & Expand Inventory

NYSE: MPO | www.MidstatesPetroleum.com 9

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SLIDE 10

126 214 277 110 192 253

13 22 29

248 428 559

100 200 300 400 500 600 Open Hole Conventional Open Hole + Recomplete EUR (MBOE) Oil (MBBL) Gas (MBOE) NGL (MBBL)

Mississippian Lime EUR by Completion

NYSE: MPO | www.MidstatesPetroleum.com 10

Population included is for Q1’14 Look back

  • 6 Open Hole
  • 5 Conventional
  • 9 Open Hole + Recomplete

D&C $2.2 - $2.6mm D&C $3.4 - $3.8mm D&C $3.4 - $4.1mm

High-Grade & Expand Inventory

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SLIDE 11

Completed as OH Monitored Performance Re-entered & performed multi- stage frac Prod Rates post frac-stimulation

OH & Re-Entry Lone Eagle 3H-8

Oil Gas Total Open Hole Completions Re-Entered & Frac’d No Re-Entry Planned 45 36 9

High-Grade & Expand Inventory

  • Evaluate matrix/natural fracture contribution without multi-stage frac job
  • Open hole acid wash, flow back, monitor performance, and decide on re-entry candidates
  • Post frac provides solid rates, steadier decline, lower GOR and increased incremental reserves

Mississippian Lime: Open Hole & Re-Entry

NYSE: MPO | www.MidstatesPetroleum.com 11

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Enhanced Upper Miss Lime Well Economics

Key Economic Parameters Oil 24-hr IP (bpd) 550 Gas 24-hr IP (mcfd) 3,003 NGL Yield (bbl/Mmcf) 65 Gross EUR, post-processing, 3-stream (MBoe) 546 D&C Cost ($mm) $3.6 F&D Cost, ($/boe) $8.42 BT IRR (%) 102% BT NPV-10 ($mm) $4.9

NYSE: MPO | www.MidstatesPetroleum.com 12

High-Grade & Expand Inventory

Type Curve Assumptions – Upper Miss (Enhanced) Upper Miss (Enhanced) Type Curve IRR Sensitivity

0% 50% 100% 150% 200% $85 / $4 $90 / $4.50 $95 / $5 $100 / $5 BT IRR %

1 10 100 1,000

1 7 13 19 25 31

Boed Months

  • Enhanced permeability and porosity
  • Geo-steered in zone
  • ~75 additional enhanced locations

across acreage identified with 3-D seismic

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Mississippian Lime: Differentiated Performance

  • Continuing Top Tier overall well performance in the Mississippian Lime
  • 169 wells on production >30 days: Average peak 30-day rate of 565 Boe/d

Allocate Rigs Where Returns are Highest

Peak 30-Day Production Rates through July 2014

Nearly 50% of all wells are >500 Boe/d; for those wells, expected IRRs are >100%

3% 16% 35% 36% 10% 61 178 371 710 1,483 0% 5% 10% 15% 20% 25% 30% 35% 40% 45% 50% 1 10 100 1,000 <100 101-250 251-500 501-1000 >1000

Percentage of Total Operated Wells Drilled Average 30-Day Peak Rate (Boe/d)

Boe/d

NYSE: MPO | www.MidstatesPetroleum.com 13

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Water Disposal System Monetization Potential

System Overview – Woods and Alfalfa

  • Six SWD wells and strategically located pipeline

network of ~100 miles creating efficient loop

  • 345,000 BBL/d of capacity in loop; collecting skim oil
  • Midstates disposes ~160,000 BBL/d into the Arbuckle
  • Eight total SWD wells across Woods and Alfalfa

allows for significant growth up to ~430,000 BBL/d

Options to Unlock Value

Value Proposition

  • Significant untapped 3rd party capacity potential
  • At a disposal charge of $0.50 - $1/BBL and 5-10x

EBITDA, creates attractive value proposition

  • Opportunity to further enhance financial position

NYSE: MPO | www.MidstatesPetroleum.com 14

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Mississippian Lime Summary

  • “Best in class” EURs, 30 day rates, and operating costs in Miss Lime Play
  • 7 rig program in Q3’14
  • Near-term development plan calls for 4 wells per section with +90% IRR’s
  • Down-spacing to 7 laterals per section being actively tested over next few months
  • Optimization of completions continues – open hole acid wash followed by cased

hole re-completions using 25 stage slickwater fracs

  • Significant value upside to be tested in 2014 from
  • Upper Miss Lime porosity intervals, Middle Miss Lime potential, multiple additional horizons
  • 900+ potential upper Miss locations with estimated net resource of ~225 MMBoe
  • Additional ~700 potential locations in other prospective horizons being further

evaluated with estimate net resource potential of ~125 MMBoe

NYSE: MPO | www.MidstatesPetroleum.com 15

Focus on Miss Lime & Anadarko

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SLIDE 16

MPO Acreage Apache Acreage

8,004 8,404 8,454 8,376

  • 2,000

4,000 6,000 8,000 10,000 Q2 2013Q3 2013Q4 2013Q1 2014Q2 2014 2014E Gas NGL Oil 8,885

  • Strong acreage position, gaining and leveraging knowledge
  • Solid, repeatable results in the de-risked Cleveland with encouraging early results in other horizons
  • 850+ potential locations in four primary target horizons on our acreage with estimated net resource

potential of ~90 MMBoe

  • Evaluating additional ~700 potential locations in other prospective horizons on our acreage with estimated

net resource potential of ~125 MMBoe Net Production (Boe/d)

Anadarko Basin: Liquids-Rich Targets

Focus on Miss Lime & Anadarko

8,600-9,400

NYSE: MPO | www.MidstatesPetroleum.com

Jones Acreage Sandridge Acreage Chesapeake Acreage

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Formation Wells Spud Wells with 30 day rates Peak 30 Day rates Boe/d Cleveland 36 34 380 Marmaton 14 13 279 Cottage Grove 10 8 389 Tonkawa 5 3 421 Total 65 58 362

Anadarko Basin: Prolific Multi Stacked Horizons

  • Cleveland and Marmaton
  • Well established
  • Good well control and predictability
  • Solid results
  • Cleveland average 30 day peak 380 Boe/d
  • Two Marmaton wells with 30 day rates >400 Boe/d
  • Tonkawa and Cottage Grove
  • Considerable upside potential
  • Early results show higher oil percentages
  • Tonkawa Miskel well 30 day peak 851 Boe/d
  • Cottage Grove Danny well 30 day peak 679 Boe/d
  • Cottage Grove Mason well 30 day peak 711 Boe/d
  • Largely untapped on our acreage
  • Sands are not uniform; finding the right areas is

critical to generate highest return wells

  • Upside locations exist in multiple formations,

which have been horizontally and vertically drilled by other companies in the past

High-Grade & Expand Inventory

NYSE: MPO | www.MidstatesPetroleum.com 17

(1) (1) Excluding wells with mechanical issues

Peak 30-Day Production Rates through July 2014

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SLIDE 18

Tonkawa NW Peak Well Economics

NYSE: MPO | www.MidstatesPetroleum.com 18

Expand & High-Grade Inventory

  • Good early results in Tonkawa
  • Miskel well 30 day IP 851 BOE/d exceeds

type curve assumptions

  • ~44 additional locations across acreage

Type Curve Assumptions – Tonkawa NW Peek

Key Economic Parameters Oil 24-hr IP (bpd) 214 Gas 24-hr IP (mcfd) 232 NGL Yield (bbl/Mmcf) 100 Gross EUR, post-processing, 3-stream (MBoe) 296 D&C Cost ($mm) $3.5 F&D Cost, ($/boe) $12.96 BT IRR (%) 66% BT NPV-10 ($mm) $4.2

High-Grade & Expand Inventory

Tonkawa NW Peek Type Curve

1 10 100 1,000

1 7 13 19 25 31

Boed Months

IRR Sensitivity

0% 25% 50% 75% 100% $85 / $4 $90 / $4.50 $95 / $5 $100 / $5 BT IRR %

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Anadarko Peak Prospect – Tonkawa and Cottage Grove Potential Upside

MPO Acreage Tonkawa Horizontal Cottage Grove Horizontal Tonkawa Potential Location Cottage Grove Location

  • 52 Potential Tonkawa locations
  • 44 future locations
  • 8 drilled locations
  • 41 Potential Cottage Grove locations
  • 25 future locations
  • 16 drilled locations
  • 5 Additional Tonkawa & Cottage

Grove wells planned for 2H 2014

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Anadarko Summary

  • Focused on drilling/completion efficiencies and cost reduction in Cleveland
  • 2015 development plan has 3 rigs with +50% IRR’s
  • Significant potential in the Tonkawa and Cottage Grove
  • Focused on high-grading locations
  • 850+ potential locations on four primary target horizons with estimated net

resource potential of ~90 MMBoe

  • Additional ~700 potential locations in other prospective horizons being further

evaluated with estimated net resource potential of ~125 MMBoe

NYSE: MPO | www.MidstatesPetroleum.com

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Focus on Miss Lime & Anadarko

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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) – Net Resource Potential: 20 MMBOE (Mean); 61 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: Konik (Cockfield) and Bayou Cholpe (Lower Wilcox) – 2015 wells: 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%

Options to Unlock Value

Fleetwood Overview

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SLIDE 22

%Liquids 66% 57% 56% 49% % Oil 45% 30% 39% 38% $42.35 $36.47 $33.16 $31.86 $20.00 $25.00 $30.00 $35.00 $40.00 $45.00 MPO Peer 1 Peer 2 Peer 3

Margin Expansion Enhances Financial Stability

  • Q2’14 cash operating costs per Boe

lowest since IPO

  • LOE and G&A improvements are

sustainable, with potential for continued improvement

(1) Mid Con Peer Group includes: Jones, Newfield and Sandridge (2) See reconciliation in the appendix (3) Midpoint of guidance range for FY 2014

Expand Cash Margins & Control Costs

NYSE: MPO | www.MidstatesPetroleum.com 22

Cash Operating Expense(2) Improvements Over Time

$9.51 $9.83 $8.32 $7.04 $7.71 $6.79 $7.00 $6.70 $7.56 $4.58 $4.27 $3.89 $3.90 $3.21 $4.08 $3.68 $3.09 $2.31 $2.93 $1.94 $2.46 $0.99 $1.00 $1.09 $1.01 $0.93 $20.29 $21.07 $16.98 $14.61 $15.62 $13.64 $13.60(3) $0.00 $5.00 $10.00 $15.00 $20.00 $25.00 Q1 2013 Q2 2013 Q3 2013 Q4 2013 Q1 2014 Q2 2014 2014E $/BOE Gathering & Transportation Severance & Other Taxes G&A (Cash) OpEx

  • Adjusted EBITDA enhanced by:
  • Cash operating cost

management

  • Improved well performance
  • Focus on oil and liquids rich

areas 2014 YTD EBITDA / Boe vs. Mid Con Peer Group(1)

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SLIDE 23

D&C 85 - 90%

Land, Seismic, Infrastructure 10 - 15%

By Type Operating Capital Guidance: $500 to $550 million

  • ~68% Miss Lime, 29% Anadarko, and 3% Gulf Coast
  • Excludes capitalized interest and G&A, asset retirement obligations,
  • ffice and other expenditures

9-10 rigs running in Q3’14

  • 7 rigs in the Miss Lime
  • 2-3 rigs in the Anadarko Basin

Capital Efficiency and Discipline

  • Primary spend on drilling and completion activities
  • Drilling highest rate of return projects / areas
  • Continue strategic acreage purchases in Miss Lime and Anadarko

2014 Operating Capital Expenditures in line with Adjusted EBITDA

Demonstrating Capital Efficiency

Balance 2014 Capital with Adjusted EBITDA

Gulf Coast ~3% Miss Lime ~68% Anadarko ~29%

By Area

NYSE: MPO | www.MidstatesPetroleum.com 23

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SLIDE 24

Enhanced Financial Position

Deliver Financial Stability

$ millions

  • Strong EBITDA growth
  • Q2’14 Adjusted EBITDA ~$122mm, projected $500 - $550mm for 2014
  • Projected debt/EBITDA of ~3.5x by year end 2014
  • Liquidity @ June 30, 2014 : $150 mm
  • No new debt or equity raises required through 2015 to execute strategy
  • Improving balance sheet
  • Reviewing additional property sales, JVs and other options
  • Continue to add hedges to secure 2015 cash flow

NYSE: MPO | www.MidstatesPetroleum.com 24 Cash Balance Borrowing base Net Liquidity June 30 Liquidity 30,000 $ (355,000) $ 475,000 $ 150,000 $ Revolver

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SLIDE 25

Refocused Energy

NYSE: MPO | www.MidstatesPetroleum.com 25

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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SLIDE 26

Appendix

NYSE: MPO | www.MidstatesPetroleum.com 26

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SLIDE 27

Guidance (as of August 6, 2014)

NYSE: MPO | www.MidstatesPetroleum.com 27 Q3 2014

Daily Production (Boe/day)(1)

Miss+ Anadarko LA Miss+ Anadarko LA By Area ~69% ~26% ~5% By Area ~66% ~27% ~7% Oil 35-40% 45-50% 60-65% Oil 35-40% 45-50% ~70% NGL 20-25% 20-25% 15-20% NGL 20-25% 20-25% ~20% NG 40-45% 30-35% 20-25% NG 40-45% 30-35% ~10%

Operating Capital Expenditures (2)

~71% Miss+, ~27% Anadarko, 2% LA ~68% Miss+, ~29% Anadarko, 3% LA

Capitalized Interest Lease Operating and Workover Expense Gathering and Transportation Expense Severance and Ad Valorem Tax General and Administrative Expense Cash Non Cash DD&A Expense Income Tax Provision (deferred & non-cash)

FULL YEAR 2014

$25.00 - $27.00 / boe 0% - 5% $25.00 - $27.00 / boe 0% - 5% 32,000 - 35,000 (1) $500mm - $550mm $16mm - $22mm $6.75 - $7.25 / boe 4% - 5% of revenue $125mm - $135mm 34,000 - 35,000(1) $1mm - $2mm $38mm - $42mm $10mm - $11mm $6mm - $8mm $4mm - $6mm $3mm - $3.5mm $10mm - $12mm $6.75 - $7.25 / boe 4% - 5% of revenue

1) Oil Price Differential & Transportation Information

  • Mississippian: WTI w/ $5.00 discount, including transportation
  • Anadarko: WTI w/ $3.50 discount, including transportation
  • Louisiana: WTI w/ LLS Premium, transportation ~2.50/bbl (note: Actual realizations reflect that LA oil revenues are paid on a 30 day delayed basis)

2) Excluding capitalized interest and G&A, asset retirement obligations, office and other expenditures

Miss+ = Mississippian + Hunton

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SLIDE 28

Hedging Summary (as of Sept 9, 2014) (4)

(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 June 30, 2014. (3) Includes 101,000 Mmbtus that priced in the 2nd quarter of 2014, but had not cash settled as of June 30, 2014. (4) Includes new 1Q & 2Q 2015 oil hedges that were added in July & August 2014

NYSE: MPO | www.MidstatesPetroleum.com 28

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SLIDE 29

Adjusted EBITDA Reconciliation

For the Three Months Ended June 30, For the Three Months Ended March 31, For the Year Ended December 31, 2014 2014 2013 2012 2011 Adjusted EBITDA reconciliation to net income (loss): Net income (loss) $ (2,098) $ (83,645) $ (343,985) $ (150,097) $ 16,657 Depreciation, depletion and amortization 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

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

  • Interest income

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

NYSE: MPO | www.MidstatesPetroleum.com 29

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SLIDE 30

Cash Operating Expenses Reconciliation

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

  • (453,310)

Other (609) (330)

  • (614)

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

NYSE: MPO | www.MidstatesPetroleum.com 30

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SLIDE 31

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 31

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 March 30, 2014: 21.63 $ 14,060,800 1,041,541 1,278,255 Adjusted liquidation preference at March 30, 2014: 1,103.23 $ 365,580,800 $ 27,080,059 33,234,618 Accrued dividend amount at June 30, 2014:

  • $

7,311,616 541,601 664,692 Adjusted liquidation preference at June 30, 2014: 1,103.23 $ 372,892,416 $ 27,621,660 33,899,311 Calculation

Conversion into Common Shares @ $11.00

Accumulated dividend amount at 6/30/14 7,311,616 Conversion price 11.00 $ Additional shares 664,692 Share price at June 30, 2014 7.23 $ Dividend amount as calculated 4,805,726 $ 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 Second Quarter 2014

(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.

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SLIDE 32

Mississippian Lime: Statistics

Position

  • ~77,500 net acres in the Mississippian Lime in Woods &

Alfalfa counties Oklahoma (1)

Interest

  • Operate 92% of ~240 producing wells

– 70% avg. WI and 55% NRI

Product Mix and Pricing

  • 40% Oil, 20% NGL, & 40% Gas
  • Oil Realizations: ~$5 discount to WTI
  • Gas Realizations: ~ $0.20 discount to Henry Hub

Typical Well Data

  • Shallow drilling depths at ~6,000’ TVD with ~4,600’ laterals
  • Avg. D&C well costs for conventional Miss well ~$3.4mm

(targeting $3mm)

  • Approximate EUR 400 to 550 Mboe
  • Average F&D: ~$10.00 / Boe
  • Expected average IRR on a go forward basis: ~90%
  • Inexpensive salt water disposal into the Arbuckle formation

(1) 90,400 total net acres in Oklahoma as of June 30, 2014, comprised of 81,500 net acres in the Mississippian Lime and 12,900 net acres in the Hunton in Lincoln County, Oklahoma

NYSE: MPO | www.MidstatesPetroleum.com 32

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SLIDE 33

Anadarko Basin: Statistics

MPO Acreage

Position

  • 131,500 net acres (66% held by production) with

100,500 acres in Northeast Texas Panhandle and 31,000 acres in Western Oklahoma

Interest

  • Operate 79% of ~340 producing horizontal wells

– 69% avg. WI and 54% NRI

Product Mix and Pricing

  • 45-50% Oil, 20-25% NGL, & 30-35% Gas
  • Oil Realizations: ~$3.50 discount to WTI
  • Gas Realizations: ~ $0.20 discount to Henry Hub

Typical Well Data

  • Drilling depths at ~6,000’ to ~8,000 TVD with ~4,000’

to ~4,300’ laterals and 15 to 17 frac stages

  • Avg. D&C well costs for Cleveland well ~$3.3mm
  • Approximate EUR: 175 Mboe
  • Average F&D: ~$20 / Boe
  • Expected average IRR on a go forward basis: ~50%

NYSE: MPO | www.MidstatesPetroleum.com 33

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SLIDE 34

Midstates Petroleum Company


Corporate Headquarters 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 Al Petrie

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

Chris Delange

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

Investorrelations@midstatespetroleum.com Direct Line: (713) 595-9333 www.MidstatesPetroleum.com NYSE: MPO | www.MidstatesPetroleum.com 34