Barclays CEO Energy Conference

1. 1
Wednesday, September 3, 2014

2. 2
DISCLAIMER
Forward Looking Statement
This presentation includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the
Securities Exchange Act of 1934, as amended. These statements express a belief, expectation or intention and are generally accompanied by words that convey
projected future events or outcomes. The forward-looking statements include statements about the company’s future operations, rig counts, drilling inventory
and locations, acreage positions, corporate strategies, including the exploration and development of the Midcontinent and potential monetization of saltwater
disposal infrastructure, generating high rates of return from quality assets in our focus areas, estimates of oil and natural gas production, projected capital
expenditures and other costs, liquidity and leverage, debt maturities, price realizations, projected earnings, and hedging strategies. We have based these
forward-looking statements on our current expectations and assumptions and analyses made by us in light of our experience and our perception of historical
trends, current conditions and expected future developments, as well as other factors we believe are appropriate under the circumstances. However, whether
actual results and developments will conform with our expectations and predictions is subject to a number of risks and uncertainties, including the volatility of oil
and natural gas prices, our success in discovering, estimating, and developing oil and natural gas reserves, the availability and terms of capital, our timely
execution of hedge transactions, credit conditions of global capital markets, changes in economic conditions, regulatory changes and other factors, many of
which are beyond our control. We refer you to the discussion of risk factors in Part I, Item 1A – “Risk Factors” of our Annual Report on Form 10-K for the year
ended December 31, 2013 and in comparable “Risk Factors” sections of our Quarterly Reports on Form 10-Q filed after the date of this presentation. All of the
forward-looking statements made in this presentation are qualified by these cautionary statements. The actual results or developments anticipated may not be
realized or, even if substantially realized, they may not have the expected consequences to or effects on our company or our business or operations. Such
statements are not guarantees of future performance and actual results or developments may differ materially from those projected in the forward-looking
statements. We undertake no obligation to update or revise any forward-looking statements.
The SEC permits oil and natural gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves, as each is defined by the
SEC. At times we use the term "EUR" (estimated ultimate recovery) and refer to their location and potential to provide estimates that the SEC’s guidelines
prohibit us from including in filings with the SEC. These estimates are by their nature more speculative than estimates of proved, probable or possible reserves
and, accordingly, are subject to substantially greater risk of being actually realized by the company. For a discussion of the company’s proved reserves, as
calculated under current SEC rules, we refer you to the company’s Annual Report on Form 10-K referenced above, which is available on our website at
www.sandridgeenergy.com and at the SEC’s website at www.sec.gov.
Regulation G Disclosure: This presentation includes certain non-GAAP financial measures as defined under SEC Regulation G. A reconciliation of those
measures to the most directly comparable GAAP measures is available on our website at www.sandridgeenergy.com.

3. 3
SANDRIDGE MISSION
Premier Mid‐Continent Company
MISSION STATEMENT
Our Mission at SandRidge
is to create the premier,
high-return, growth-oriented,
resource conversion company,
focused in the Mid-Continent
region of the United States.
1

4. a) Non-GAAP financial measure. Refer to the Disclaimer slide for additional
4
disclosure
b) Pro Forma for the Q1’14 Gulf of Mexico divestiture
c) SandRidge consolidated reserves as of YE2013 including royalty trusts
d) Based on YE13 SEC pricing ($93.42/$3.67)
SANDRIDGE COMPANY OVERVIEW
MARKET VALUE ($ in millions)
Market Cap (08/29/2014) $2,590
Net Debt(a) 2,276
Preferred Stock 765
Enterprise Value $5,370
ASSET OVERVIEW(b)(c)
Q2’14 Production (MBoe/d) 69.8
Proved Reserves (MMBoe) 377
% Reserves as Liquids 46%
YE13 PV10 Value ($Bln)(d) $4.1
• Rig counts are projected averages for 2014
www.SandRidgeEnergy.com 2
SD Quick Facts
• Fractured Carbonate Focus
• Mid-Continent, Horizontal
Mississippian Leader
• Sub-$3.0MM/well, 380 MBoe EUR
• Stacked Pay Development
• $1.5Bln Capex Plan
• $919MM Cash at Q2’14

5. 5
INVESTMENT THESIS
3
20+% Production Growth, 30+% EBITDA
Growth & Flattish Capex
• Growth program continues to improve
– New zones (Chester, Woodford), New areas (Garfield)
– Better than type curve results
• Base assets performing well
– Consistent decline ratios, GOR and EURs
• Approximate doubling of production in three years
• Operating leverage yields higher EBITDA growth
• Outspend shrinks year over year
• Plus infrastructure, new zone, and expanding footprint upsides
• Excess liquidity and no bond maturities until 2020
• Pursuing unlock of infrastructure value
Refined Business Model
FOCUSED
Strategy, Execution and Culture
are Focused
COMPETITIVE ADVANTAGE
Established Infrastructure, Sizable
Leasehold and Vast Knowledge Base
ACTIONABLE GROWTH
Confidence in the Drilling Inventory
and Asset Quality
INNOVATION
Team Mindset of Continuous
Improvement
UPSIDES
Multi-zones, Appraisal Areas
and SWD Business
FUNDED
Excellent Liquidity, Leverage,
and Visible Funding into Future
www.SandRidgeEnergy.com

6. * STRIP 8/1/2014
6
ACTIONABLE GROWTH WITH UPSIDES
20+% Production Growth, 30+% EBITDA Growth & Flattish Capex
Stacked Oily Pay Zones
Significant Acreage Position
FOCUSED
*
Improving Already Strong Returns
www.SandRidgeEnergy.com 4

7. ACTIONABLE
• Confident in multi-year
drilling program
• Existing focus area position
provides >4,500 locations
• PDP base decline is flattening
• Assumes average capital
expenditure program of
~$1.55 Bln
• Well cost improvements from
$3.0 to $2.7 MM
7
MULTI‐YEAR PRODUCTION GROWTH
Confidence in Asset Base and Execution
2016 Activity
15 %
Decline
GROWTH
www.SandRidgeEnergy.com 5

8. 8
Q2’14 – CONTINUED STRONG WELL RESULTS RESULTS
Focus and Innovation Yield Exceptional
Operating Results in the Second Quarter
Mississippian Success
• 412 Boe/d 30-day IP, 122 laterals (30% above type curve)
• 7 laterals over 1,000 Boe/d in 4 counties
• Garfield County net production ramped 400% to 5,000 Boe/d in 1H’14
– 407 Boe/d 30-day IP (54% oil), 21 wells
– 7 rig program through YE’14
Chester Success
• 365 Boe/d 30-day IP (69% oil), 9 wells
– 3 rig program through YE’14
Woodford Success
• 360 Boe/d 30-day IP (84% oil)
– New geologic model, second well completing in Q3’14
www.SandRidgeEnergy.com 6

9. 9
• Record low Q2’14 Drilling and Completion (D&C) lateral costs of $2.85 MM
– +$1 MM decrease in capital since Q1 2012
– 97% Electric Submersible Pump (ESP) implementation rate in Q2’14
• Primary D&C cost saving in 2014 linked to innovation championed by SD teams:
– Pad drilling: 80% of Q2’14 wells drilled from multi-well pads
– Multilateral drilling: Stacked and Co-planar Dual Laterals, Trilaterals and
Full Section Development
– Wellsite facilities design improvements:
– Centralized tank batteries
– Commingled tank batteries
– Centralized Salt Water Disposal (SWD) systems
• Record low LOE at $6.69 per Boe
FOCUSED
MATERIAL WELL COST AND LOE REDUCTION
Mississippian Leader
$2.85MM /Well
$6.69 /boe
www.SandRidgeEnergy.com 7

10. 10
TARGETING BREAKOUT ECONOMICS
Ahead of Schedule, Reducing Well Costs INNOVATION
• Already strong well economics improving as costs
come down
• Breakout innovations on well design could both:
– Enhance returns
– Expand focus areas
• Value enhancing projects in motion
– Completion techniques
– Sectional development
– Shared facilities
– Artificial lift management system
• Expand competitive advantages
− Salt water disposal
− Electrical distribution system
• Multi-zone appraisal program
*
* 8/1/2014 STRIP
www.SandRidgeEnergy.com 8

11. 11
2014 MISSISSIPPIAN PUD TYPE CURVE
Actual Performance Consistently Above Type Curve FOCUSED
200
180
160
140
120
100
80
60
40
20
-
0 1 2 3 4 5 6 7 8 9 10
www.SandRidgeEnergy.com 9
350
300
250
200
150
100
50
-
Cumulative Production (Mboe)
Avg. Boe/d
Years
Type Curve Daily Avg. Rate Type Curve Cum Production PDPs
GAS: 1.2 Bcf
30 Day IP(b) (Mcf/day)
1st Year Decline(a)
B Factor
848
65%
1.83
NGL: 64 MBbls
Yield (Bbls/MMcf)
Shrink
47.5
87.3%
Oil: 118 MBo
30 Day IP (Bo/day)
1st Year Decline(a)
B Factor
176
80%
1.41

12. 12
MISSISSIPPIAN WELL PERFORMANCE
Continued Improvement
Type Curve
176 Bbl/d
MULTI-YEAR
GROWTH
www.SandRidgeEnergy.com 10
Type Curve
849 Mcf/d

13. 13
MISSISSIPPIAN WELL EURS
Continued Improvement
MULTI-YEAR
GROWTH
www.SandRidgeEnergy.com 11
20%
18%
16%
14%
12%
10%
8%
6%
4%
2%
0%
% of Wells
1 EURs are as of Year-End 2013
2 EURs are per the Company’s estimates as of Mid-Year 2014
EUR (MBoe)
COMMERCIAL
1 2
1
Wells Prior to 2013 2013 Wells 2014 Wells

14. 14
MID‐CONTINENT FOCUS AREA
Deep Understanding of the Play FOCUSED
100 MILES SD LEASEHOLD
www.SandRidgeEnergy.com 12
• Shallowest Decline Profile
• Higher EUR Distribution
• Geology Most
Understood
• Stacked Pay Potential
• Highest 30 Day Gas IPs
• Low H2O Cut
• Upside as Gas Prices Rise
• Chester Delivering Above
TC Oil Rates
• Multi Laterals Decreasing
per Lateral CAPEX
• High Density Fracs
Potentially Impactful
• 3D Required to Define Fracture Trends
• Positive Multi Lateral Results
• Highest 30 Day Oil IPs
• Highest Liquids %
• Lowest H2O Cut
• Improving EURs with Time
• Dual Laterals Exceeding TC
~650,000 Acres in Focus Area
• Miss Exhibiting Tightest
Performance Distribution
• Unlocked Woodford Potential
• Potential for Extensive Multi
Lateral Development

15. 15
FOCUSED
MULTI‐ZONE DRILLING LOCATIONS
Many Years of Drilling Ahead
Upper Miss
HZ Wells to Sales 849
Locations 2,668
Marmaton
HZ Wells to Sales 1
Locations TBD
Chester
HZ Wells to Sales 5
Locations 180
Middle Miss
HZ Wells to Sales 143
Locations 857
Lower Miss
HZ Wells to Sales 25
Locations 319
Woodford
HZ Wells to Sales 5
Locations 486
High-Graded Locations to Drill 4,510 wells
Emerging Un-Risked Locations >8,000 wells development
www.SandRidgeEnergy.com 13
Note: Drilling location information as of 03/04/14

16. 16
APPLYING SEISMIC TECHNOLOGY
Understanding The Rock INNOVATION
KS
OK
COMPLETED PLANNED SD LEASEHOLD
100 MILES
www.SandRidgeEnergy.com 14
2013 - 730 square miles of 3D data acquired
2014- 1,070 square miles of new 3D data to acquire
2015 - 800 square miles of new 3d data to acquire
Parallel
fault trend
Main fault
trend

17. 17
MULTILATERAL APPROACH IS SUCCESSFUL
Changing how carbonates are developed INNOVATION
Achieving Breakthrough Cost Upsides with Production Uplift
• Multilateral success achieved on three dual stacked laterals and one co-planar
well in Grant, Alfalfa, and Harper counties during Q2’14
www.SandRidgeEnergy.com
• Four wells averaged $2.5 million per lateral
– 83% of type curve cost
– 108% of the type curve 30-day IP
• Six rigs are currently planned to drill multilateral wells through the
second half of the year
• Broader sanction of multilaterals expected in 2015
– 18% of 2H14 wells involve multilaterals (two or more laterals from a
single vertical well)
Dual Stacked Lateral
Co-Planar Dual Lateral
15

18. 18
INNOVATION / UPSIDE
FSD offers up to 34% more section for 26% less
capex
Full Section Development
• Fracture stimulates 34% more interval: 22,000’ vs typically 16,400’ with four single
laterals
• Rock integrity of our carbonates (vs shales or sandstones elsewhere) allows for
effective use of open hole multilaterals
• 130% IRR* to drill and complete a multilateral Full Section Development at
$2.3MM per lateral vs 65% IRR* for a single lateral well at $2.9 MM
• $3.2MM savings per square mile section ($9.1MM vs $12.3MM):
INNOVATION
Full Section Development
(For Illustrative Purposes)
www.SandRidgeEnergy.com
Full Section Development D&C Cost Savings Detail $M
Tank Battery, SWD, Powerline and Connection $ 1,350
Intermediate 7" Casing and ESP Savings (One Each vs Four) $ 1,100
Drilling Location, Rig Move and Reduced Drilling Days $ 1,000
Rentals and Miscellaneous $ 350
Incremental cost to frac an additional ~6000’ of interval $ (600)
Total Savings $3,200
* Strip as of 8/1/14 16

19. Most Efficient
SWG Operator in
the midcontinent
– Various tubing sizes based
produced water for ~80 years
• Frac flowback is < 5% of total
interconnected – maximizing
system flexibility
19
SALTWATER GATHERING & DISPOSAL (SWG) UPSIDES
• Produce
– ~1 million barrels of water per day at mid 2014 from 1,300
Mid-Continent producers
• Gather & Process
– Produced water is transported to disposal location through
SD owned pipeline system
– Typically Polyethylene pipe (8” to 12” diameter) connected
to producing wells, buried under ground
– Water is cleaned and treated at disposal location
• Inject
– + 170 disposal wells as of mid-2014,
adding ~50 wells per year
– Many take water on a vacuum (hydrostatic
pressure is adequate to achieve disposal)
• $590 MM invested by the end of 2014
• Average capacity of 15,000
BWPD per well
– Low pressure pumps at
most locations
on needed capacity
– Open hole Arbuckle
completion
• Pressure and volume
continuously monitored
• Arbuckle has been taking
• Gathering system is
www.SandRidgeEnergy.com 17
Produced water gathered and sequestered into
Arbuckle through cost effective infrastructure

20. 20
FINANCIAL STRENGTH
• Contains Non-GAAP financial measures. Refer to slide 2 for additional disclosure.
a) Leverage Ratio represents Consolidated Leverage Ratio calculated pursuant to the terms of the Senior Credit Facility
b) Liquidity represents the quarter ending cash balance and revolver availability, adjusted for letters of credit
FUNDED
• Excellent cash and liquidity
– $919MM cash at 6/30/14
– Fully undrawn credit facility of $775 MM
– Total liquidity of $1.7 Bln
• Comfortable leverage
– 3.2x Q2’14 leverage ratio
– No near term bond maturities
• Growing cash flow
– Product of 20-25% CAGR production growth
– Keeps leverage in check
– Shrinks capex outspend of cash flow
• Significant oil hedges at strong prices provide
cash flow stability and visibility
www.SandRidgeEnergy.com 18

21. 21

22. 2014 PRODUCTION GUIDANCE GUIDANCE
www.SandRidgeEnergy.com 22
(A) 2013: 11.3 MMBoe of non-recurring production related to divested Permian and GoM assets
(B) 2014: 1.3 MMBoe of non-recurring production related to divested GoM assets (2/25/2014 closing)
20

23. 23
CREDIT PROFILE
• ~$1.7 Bln liquidity at Q2’14
– $919MM cash
– Fully undrawn credit facility of $775 MM
• 3.2x Q2’14 leverage ratio
• Borrowing base of $775MM undrawn; reserve
value provides for significant increase potential
• Significant oil hedges at strong prices provide
cash flow stability and visibility
• Contains Non-GAAP financial measures. Refer to slide 2 for additional disclosure.
a) Leverage Ratio represents Consolidated Leverage Ratio calculated pursuant to the
terms of the Senior Credit Facility
b) Liquidity represents the quarter ending cash balance and revolver availability,
adjusted for letters of credit
APPENDIX
www.SandRidgeEnergy.com 21

24. 24
CAPITAL STRUCTURE OVERVIEW APPENDIX
Senior Notes Preferred Stock
8.75% Sr Notes due 2020 $445
7.5% Sr Notes due 2021 1,179
8.125% Sr Notes due 2022 750
7.5% Sr Notes due 2023 821
Total $3,195
($ in millions)
8.5% Convertible Perpetual Preferred(a) $265
6.0% Convertible Preferred(b) 200
7.0% Convertible Perpetual Preferred(c) 300
Total $765
Credit Rating Corp Rating Outlook
Credit Rating Corp Outlook
Moody's B1 Stable
S&P B Stable
($ in millions)
(d)
(d)
(a) Convertible at holder’s option at $8.0125 per common share; convertible after Feb 20, 2014 (b) Convertible at holder’s option at $10.856 per common share; automatic conversion after Dec 21, 2014
(c) Convertible at holder’s option at $7.7645 per common share; convertible after Nov 20, 2015 (d) Weighted Average Maturity excludes Credit Facility amounts
www.SandRidgeEnergy.com 22

25. 25
CONSOLIDATED HEDGE POSITION
Q3 2014 ‐ 2016
2014: 95% of Liquids Volumes Hedged 2015: 10.2 MMBBls Liquids volume hedged
97% of liquids revenue hedged
2.1 MMBbls
$99.08/Bbl
4.1 MMBbls
$70.00 -$90.20 -
$100.00/BBL
5.6 MMBBLS
$92.44/BBL
4.6 MMBbls
$76.47 -$90.28 -$103.48/BBL
3-Way
Collars
SWAPS 64%
UNHEDGED
31%
5%
2014: 59% of natural gas volumes Hedged
60% of gas revenue hedged
24.8 BCF
$4.28/MCF
SWAPS UNHEDGED
3-WAY
COLLARS
2015: 16.4 BCF natural gas volumes Hedged
15.4 BCF
$4.50/MCF
SWAPS
58%
UNHEDGED
41%
Collars 1%
0.5 BCF
$4.00-$7.78/MCF
Collars
1.0 BCF
$4.00-$8.55/MCF
SWAPS UNHEDGED
HEDGING
2016: 1.8 MMBBLS Liquids volume hedged
2016: 0 BCF natural gas volumes Hedged
• Positions displayed include royalty trusts and are displayed for July forward. Liquids hedged to NYMEX WTI; Natural Gas hedged to NYMEX Henry Hub; NGL barrels hedged at
3:1 ratio to WTI. 3-way collar and revenue calculations assume $95/bbl WTI and $4.25/Mcf NYMEX gas in 2014 and $90/bbl WTI and $4.25/Mcf NYMEX gas in 2015 and 2016.
UNHEDGED
UNHEDGED
3-Way Collars
1.8 MMBbls
$84.40 -$90.00 -$103.50/BBL
www.SandRidgeEnergy.com 23

26. 26
2013 RESERVE METRICS
Focused On The Mississippian Play APPENDIX
RESERVES PV10
Pro Forma 2013 Excluding Gulf of Mexico Proved Reserves*
SEC Pricing - $93.42 / $3.67
Liquids
MMBbls
Gas
Bcf
Equivalent
MMBoe
% $MM %
Reserves by Reservoir Status
PDP - Producing 88 708 206 55% $ 2,441 59%
PNP - Non Producing 9 57 19 5% 283 7%
PBP - Behind Pipe 1 74 14 4% 73 2%
PUD - Undeveloped 74 384 138 37% 1,306 32%
Total 173 1,223 377 $ 4,103
Reserves by Development
Total Developed 98 839 238 63% 2,797 68%
Total Undeveloped 74 384 138 37% 1,306 32%
Total 173 1,223 377 $ 4,103
434% Reserve Replacement
63% Proved Developed
25% Reserve Growth
$10.19 Organic Drilling F&D
$11.72 All-In F&D
16.7 Years of R/P Life
* Adjusted for Permian & Gulf of Mexico divestitures
• Includes non-controlling royalty trust interests
www.SandRidgeEnergy.com 24

27. 27
2014 MISSISSIPPIAN PUD TYPE CURVE
380 MBoe, 48% Liquids FOCUSED
200
180
160
140
120
100
80
60
40
20
-
350
300
250
200
150
100
50
-
Cumulative Production (Mboe)
Avg. Boe/d
Type Curve EUR YE2013
Oil (Mbo) 118
NGLs (MBbls) 64
Liquids (MBbls) 182
Gas - Shrunk (MMcf) 1,185
MBoe 380
Mcf Shrink 87.3%
NGL Yield (Bbls/MMcf) 47.5
0 1 2 3 4 5 6 7 8 9 10
Years
Type Curve Daily Avg. Rate Type Curve Cum Production
GAS: 1.2 Bcf
30 Day IP(b) (Mcf/day)
1st Year Decline(a)
B Factor
848
65%
1.83
NGL: 64 MBbls
Yield (Bbls/MMcf)
Shrink
47.5
87.3%
Oil: 118 MBo
30 Day IP (Bo/day)
1st Year Decline(a)
B Factor
176
80%
1.41
a) Represents decline from month 1 to month 13
b) Wet gas, wellhead volumes
www.SandRidgeEnergy.com 25

28. 28
2014 OPERATIONAL GUIDANCE UPDATE
PRODUCTION
Oil (MMBbls) 10.7 - 11.3
Natural Gas Liquids (MMBbls) 3.5 - 3.6
Total Liquids (MMBbls) 14.2 - 14.9
Natural Gas (Bcf) 82.6 - 84.6
Total (MMBoe) 28.0 - 29.0
CAPITAL EXPENDITURES ($ in millions)
Exploration and Production $1,230
Land and Seismic 120
Total Exploration and Production $1,350
Oil Field Services 15
Electrical/Midstream 60
General Corporate 50
Total Capital Expenditures (excl. A&D) $1,475
EBITDA from Oilfield Services
and Other ($MM) (a) $30
Adjusted Net Income
Attributable to NCI ($MM) (b) $110
Adjusted EBITDA
Attributable to NCI ($MM) (c) $145
PRICE REALIZATIONS
Oil (differential below WTI) $2.75
NGLs (realized % of WTI) 36%
Gas (differential below Henry Hub) $0.75
COSTS PER BOE
Lifting $11.15 - $13.15
Production Taxes 1.15 - 1.35
DD&A – oil & gas 15.00 - 17.00
DD&A – other 2.20 - 2.40
Total DD&A $17.20 - $19.40
G&A – cash 3.60 - 4.00
G&A – stock 0.65 - 0.80
Total G&A $4.25 - $4.80
Corporate Tax Rate 0%
Deferral Rate 0%
APPENDIX
a) EBITDA from Oilfield Services and Other is a non-GAAP
financial measure as it excludes from net income interest
expense, income tax expense and depreciation, depletion
and amortization. The most directly comparable GAAP
measure for EBITDA from Oilfield Services and Other is
Net Income from Oilfield Services and Other. Information
to reconcile this non-GAAP financial measure to the most
directly comparable GAAP financial measure is not
available at this time, as management is unable to
forecast the excluded items for future periods and/or
does not forecast the excluded items on a segment basis
b) Adjusted Net Income Attributable to Noncontrolling
Interest is a non-GAAP financial measure as it excludes
gain or loss due to changes in fair value of derivative
contracts and gain or loss on sale of assets. The most
directly comparable GAAP measure for Adjusted Net
Income Attributable to Noncontrolling Interest is Net
Income Attributable to Noncontrolling Interest.
Information to reconcile this non-GAAP financial measure
to the most directly comparable GAAP financial measure
is not available at this time, as management is unable to
forecast the excluded items for future periods
c) Adjusted EBITDA Attributable to Noncontrolling Interest
is a non-GAAP financial measure as it excludes from net
income interest expense, income tax expense and
depreciation, depletion and amortization, gain or loss due
to changes in fair value of derivative contracts and gain or
loss on sale of assets. The most directly comparable
GAAP measure for Adjusted EBITDA Attributable to
Noncontrolling Interest is Net Income Attributable to
Noncontrolling Interest. Information to reconcile this non-
GAAP financial measure to the most directly comparable
GAAP financial measure is not available at this time, as
management is unable to forecast the excluded items for
future periods
Introducing a guidance range of 28 – 29 MMBoe or
19 – 23% pro forma production growth for 2014
www.SandRidgeEnergy.com 26

29. 29
WELL COUNTS GROSS NET
Mid-Continent/Mississippian Focus
460 331
Area
Mid-Continent SWD 50 37
Permian 180 176
2014 CAPEX GUIDANCE
($ in millions)
MID-CONTINENT/MISSISSIPPIAN D&C
Focus Area $985
Appraisal 55
SWD Wells 60
Total Mid-Continent/Mississippian D&C $1,100
OTHER MID-CONTINENT/MISSISSIPPIAN
SWD Pipeline/Infrastructure $59
Workovers & Non-Op 89
Land & Seismic 102
Electrical/Midstream 50
Total Other E&P $300
Total Mid-Continent/Mississippian $1,400
($ in millions)
DRILLING AND COMPLETION (D&C)
Mid-Continent/Mississippian $1,040
Mid-Continent SWD Wells 60
Permian 110
Gulf of Mexico / Gulf Coast 10
JV Carry (205)
Total D&C $1,015
OTHER E&P
SWD Pipeline/Infrastructure $71
Workovers & Non-Op 94
Land & Seismic 120
Capitalized G&A and Interest 50
Total Other E&P $335
E&P Capital Expenditures $1,350
NON-E&P
Drilling & Oil Field Services $15
Electrical/Midstream 60
General Corporate 50
Total Non-E&P $125
Total $1,475
APPENDIX
www.SandRidgeEnergy.com 27

30. 30
Our Mission at SandRidge is to create the premier, high-return, growth-oriented,
resource conversion company, focused in the Midcontinent region of the United States.
SANDRIDGE INVESTOR RELATIONS
123 Robert S. Kerr Avenue, Oklahoma City, OK 73102
investors@sandridgeenergy.com
www.SandRidgeEnergy.com