This document discusses SandRidge Energy's operations and strategy. It provides an overview of the company, including its production, reserves, assets, and financial information. It outlines Sandridge's strategic focus on lowering well costs and improving returns in its Mississippian operations in the Midcontinent region through techniques like pad drilling, multilaterals, and shared infrastructure. The document also discusses various innovations Sandridge is pursuing to further reduce costs and boost production, such as its successful multilaterial drilling program and plans to expand full section development.

1. 1
Thursday, January 8, 2015

2. 2
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, development plans and
appraisal programs, drilling inventory and locations, reserves, acreage positions, corporate strategies, rates of return, projected capital expenditures and other
costs, liquidity, debt maturities, price realizations 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 amended Annual Report on Form 10-K/A 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 amended Annual Report on Form 10-K/A 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.
DISCLAIMER
Forward Looking Statement
www.SandRidgeEnergy.com 2

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.
www.SandRidgeEnergy.com 3

4. 4
a) Non-GAAP financial measure. Refer to the Disclaimer slide for additional
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 (1/5/2015) $742
Net Debt(a)
2,605
Preferred Stock 565
Enterprise Value $3,912
ASSET OVERVIEW(b)(c)
Q3’14 Production (MBoe/d) 79.7
Proved Reserves (MMBoe) 377
% Reserves as Liquids 46%
YE13 PV10 Value ($Bln)(d)
$4.1
• Fractured Carbonate Focus
• Mid-Continent, Horizontal
Mississippian Leader
• Sub-$3.0MM/well, 380 MBoe EUR
• Stacked Pay Development
• 2014 Capex Plan of $1.55Bln
• $590MM Cash at Q3’14
SD Quick Facts
www.SandRidgeEnergy.com 4
Focus Area Asset Map

5. 5
FOCUSED
LOWER PRICES INFLUENCE 2015
Activity, Tactics, and Costs
www.SandRidgeEnergy.com 5
Finalizing 2015 Capital Budget Plans, Will Announce in February
• Strong liquidity and hedging plus reduced capital spending
− $900MM credit facility fully undrawn; material 2015 liquids hedging
− Reducing rig count, high-grading locations, using existing infrastructure
• Commercial returns at current commodity prices to be enhanced by lower
well costs
− Some multilaterals already below $2.3MM per lateral
− Reduction in service costs could see ~$2MM per lateral
• Desire to maintain operational momentum and capabilities by:
− Continue innovating for lower well costs
− Continue expansion into new zones and areas
• Will look to improve and simplify the balance sheet in this market

6. 6
SCALE &
OPERATION
FOCUS
SANDRIDGE ENERGY
Scale, Focus, Discipline
www.SandRidgeEnergy.com 6
Activity
• Q3 2014 total company production of 80 MBoe/d, with 67 MBoe/d in
Midcontinent
• Mississippian position of 670,000 core acres, 55% HBP
• ~30 active rigs, >400 horizontal laterals per year
• ~40% production growth year-over-year in focus area
• Adding Chester, Woodford and other zones to Mississippian core
• >1.2 MMBw/d Saltwater Gathering (SWG) Operation
Financial Discipline: Cost Leader, Eye On Infrastructure Value Capture
• <$3MM per 4500’ Mississippian lateral
• Multilateral cost breakthrough: <$2.4MM per lateral
• S1 filed for SWG MLP
• Cycle time reductions and shared facility costs continue; more to come
• Focus on artificial lift program moderates base decline rates

7. 7www.SandRidgeEnergy.com 7
• Mississippian development leader: high capacity to
execute on large scale stacked pay acreage footprint
• Cost focus (per lateral, with facility and infrastructure
efficiencies and asset value)
• New Ventures: adjacent zone, acreage and new play
upsides
• Innovation: multilateral cost breakthrough
• Leverage scale and capabilities
• Infrastructure monetization strategy (S1 for SWG)
SANDRIDGE ENERGY
Midcontinent Scale, Capability and Upside
STRATEGY &
ASSET OVERVIEW

8. 8
GROWTH PLATFORM WITH UPSIDES
Stacked Oily Pay Zones
Significant Acreage Position
Improving Already Strong Returns
FOCUSED
www.SandRidgeEnergy.com 8

9. 9
• Best in class Mid-Continent drilling and completion (D&C) lateral costs
– $2.9MM per Mid-Continent single lateral
– $700M decrease in well cost since 2012
– 100% electric submersible pump (ESP) implementation rate in Q3’14
• Primary D&C cost saving in 2014 linked to innovation championed by
SD teams:
– Pad drilling: 74% of Q3’14 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
FOCUSED
MATERIAL WELL COST AND LOE REDUCTION
Mississippian Leader
www.SandRidgeEnergy.com 9

10. 10
FOCUSED
WELL COSTS CONTINUE TO IMPROVE
Plan $2.8mm For 2015 and Lower In 2016
www.SandRidgeEnergy.com 10
• Continuous improvement has reduced well costs from $3.6MM in 2012 to $2.9MM in 2014
• Multilaterals are now ~20% of the program, recently at $2.4MM per lateral
• Continued cost control initiatives plus less cost pressure given lower oil prices suggest sub-$2.7MM per lateral in 2016
Source of Additional Cost Decreases:
• Produced Water Fracs
• Multilaterals
• Ball Drop Completions
• Shared Tanks
• Pad Drilling
• Cost Control
• Lower Service Costs

11. 11
TARGETING BREAKOUT ECONOMICS
Ahead of Schedule, Reducing Well Costs
INNOVATION
• Hedges maintain strong well economics that are
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
www.SandRidgeEnergy.com 11

12. 12
2014 MISSISSIPPIAN PUD TYPE CURVE
Actual Performance Consistently Above Type Curve FOCUSED
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 12
As of 12/10/2014

13. 13
TypeCurve
176 Bbl/d
MISSISSIPPIAN WELL PERFORMANCE
Continued Improvement
MULTI-YEAR
GROWTH
TypeCurve
849 Mcf/d
www.SandRidgeEnergy.com 13

14. 14
MID‐CONTINENT FOCUS AREA
Deep Understanding of the Play FOCUSED
100 MILES SD LEASEHOLD
• Shallowest Decline Profile
• Higher EUR Distribution
• Geology Most
Understood
• Stacked Pay Potential
• Chester Delivering Above
TC Oil Rates
• Multi Laterals Decreasing
per Lateral CAPEX
• High Density Fracs
Potentially Impactful
• Highest 30 Day Gas IPs
• Low H2O Cut
• Upside as Gas Prices Rise
• 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
www.SandRidgeEnergy.com 14

15. 15
FOCUSED
MULTI‐ZONE DRILLING LOCATIONS
Many Years of Drilling Ahead
UpperMiss
HZ Wells to Sales 1,150
Marmaton
HZ Wells to Sales 1
Chester
HZ Wells to Sales 35
Middle Miss
HZ Wells to Sales 161
Lower Miss
HZ Wells to Sales 17
Woodford
HZ Wells to Sales 11
High-Graded Locations to Drill 4,510 wells
Un-Risked Locations >8,000 wells
Emerging development
Note: Drilling location information as of 12/31/14
www.SandRidgeEnergy.com 15

16. 16
NEW VENTURES CASE STUDY
Chester Oil Development
INNOVATION
• Horizontal development of legacy vertical production
• Fine grained silty sandstone, 2 distinct pay intervals
• Existing infrastructure in area
• Higher oil cut and less water production than Miss
carbonates
• Stacked lateral potential (Chester A + B)
• 2013 appraisal with 4 wells, 35 producers now online
• ~$134MM (Gross) capital investment to-date
• Growth potential with appraisal success to the south
and west of core counties
• IP: 368 Boe/d (64% oil), 16% above Miss Type Curve
www.SandRidgeEnergy.com 16

17. 17
APPLYING SEISMIC TECHNOLOGY
Understanding the Rock
INNOVATION
KS
OK
100 MILES
+25% of core counties with 3d coverage
+45% of ok core counties with 3d coverage
2013 - 730 square miles of 3D data acquired
2014 - 1,070 square miles of new 3D data acquired
Parallel
fault trend
Main fault
trend
www.SandRidgeEnergy.com 17
3d seismic reveals:
• Fractures
• Faulting
• Rockmechanics
• Reservoircompartments
• New plays

18. 18
Achieving Breakthrough Cost Upsides with Production Uplift
MULTILATERAL APPROACH IS SUCCESSFUL
Changing How Carbonates are Developed INNOVATION
• Multilateral success achieved on three dual stacked laterals and one co-
planar well in Grant, Alfalfa, and Harper counties during Q2’14
• Four Q2’14 wells averaged $2.5MM per lateral
– 83% of type curve cost
– 108% of the type curve 30-day IP
• Six Q3’14 wells averaged $2.4MM per lateral
• Six rigs are currently planned to drill multilateral wells through the
second half of the year
• Broader sanction of multilaterals expected in 2015
– Multilaterals made up 21% of the Q3’14 drilling program (two or
more laterals from a single vertical well)
Dual Stacked Lateral
Co-Planar Dual Lateral
www.SandRidgeEnergy.com 18

19. 19
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
(For Illustrative Purposes)
FullSection Development
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 www.SandRidgeEnergy.com 19

20. 20
FULL SECTION DEVELOPMENT CASE STUDY
$2.1 MM Per Lateral, Over 4x Type Curve From 4 Laterals
www.SandRidgeEnergy.com 20
INNOVATION
• Development Model:
– Full section development candidates are areas with geologically and
economically proven reservoirs in the Miss Lime
– Cost savings yield enhanced returns
– May allow for profitable development of marginal areas
• Operations:
– Laterals were drilled without any delays or problems
– Simultaneous operations utilized successfully
– Stratigraphic section changed in first lateral
leading to target change in #2
– Completed and online 9/24
Kirkpatrick Farms: First FSD Well, $8.32MM Well Cost
Peak 30-Day IP: 1,086 Boe/d (60% Oil)
10,000
Water

21. 21
SALTWATER GATHERING & DISPOSAL (SWG) UPSIDES
• Produce
– ~1.2 million barrels of water gathered and disposed per day
during Q3‘14 in the Mid-Continent and Permian Basin
• 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
– + 180 disposal wells as of mid-2014,
adding ~50 wells per year
– Many take water on a vacuum (hydrostatic
pressure is adequate to achieve disposal)
• Estimate ~$600MM invested by the end of 2014
• Average capacity of 15,000
BWPD per well
– Low pressure pumps at
most locations
– Various tubing sizes based
on needed capacity
– Open hole Arbuckle
completion
• Pressure and volume
continuously monitored
• Arbuckle has been taking
produced water for ~80 years
• Frac flowback is < 5% of total
• Gathering system is
interconnected – maximizing
system flexibility
Most Efficient
SWG Operator in
the midcontinent
Produced Water Gathered and Sequestered into
Arbuckle Through Cost Effective Infrastructure
www.SandRidgeEnergy.com 21

22. 22

23. 23
Focus and Innovation Yield Exceptional Operating Results
Operational Update
• Third quarter total company production 80 Mboe/d, 14% growth quarter-over-quarter
• Mid-Continent production grew 39% year-over-year and 19% quarter-over-quarter
to 67 Mboe/d
─ IPs remain above type curve
─ 129 laterals drilled in third quarter with 33 rigs running
─ Multilaterals applied successfully at $2.4MM per lateral
• $75MM increase in 2014 capex, mainly for land and seismic
Financial Activity
• Material hedging of oil prices over $90/Bbl through 2015
• Repurchased 27.4MM shares at $4.06, 5.6% of outstanding shares
• Credit facility upsized to $900MM; undrawn availability, expandable to $1.2 Bln
Other Themes
• Continued success in Chester and Woodford
• Capital efficiencies continue to drive increased returns
• Power infrastructure enhanced with new auto-restarts and addition of substation
APPENDIXQ3’14 – CONTINUED STRONG WELL RESULTS
www.SandRidgeEnergy.com 23

24. 24
2014 PRODUCTION GUIDANCE UPDATE
(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)
www.SandRidgeEnergy.com 24
APPENDIX

25. 25
• Contains Non-GAAP financial measures
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
c) Revolver is expandable to $1.2B with written request
• ~$1.5 Bln liquidity at Q3’14
– $590MM cash
– Fully undrawn credit facility of $900MM(c)
• 3.4x Q3’14 leverage ratio
• Significant oil hedges at strong prices provide
cash flow stability and visibility
CREDIT PROFILE
Ability to Maintain Adequate Liquidity, Reasonable Leverage APPENDIX
www.SandRidgeEnergy.com 25

26. 26
(a) Convertible at holder’s option at $8.0125 per common share; convertible after Feb 20, 2014 (b) Convertible at holder’s option at $7.7645 per common share; convertible after Nov 20, 2015
(c) Weighted Average Maturity excludes Credit Facility amounts
Senior Notes
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)
Credit Rating Corp Rating Outlook
(c)
(c)
Preferred Stock ($ in millions)
8.5% Convertible Perpetual Preferred (a) $265
7.0% Convertible Perpetual Preferred (b) 300
Total $565
Moody’s B1 Stable
S&P B Stable
Credit Rating Corp Rating Outlook
CAPITAL STRUCTURE OVERVIEW
No Principle Currently Due until 2020 APPENDIX
www.SandRidgeEnergy.com 26

27. 27
• As of 01/06/2014
• Hedge positions include contracts that have been novated to or the benefit of which have been conveyed to SandRidge sponsored royalty trusts
HEDGING OVERVIEW APPENDIX
To be updated
Liquids Q1 2015 Q2 2015 Q3 2015 Q4 2015 2015 2016
Swaps
Volumes (MMBbls) 2.29 1.73 1.01 0.55 5.59 1.46
Price ($/Bbl) $92.71 $91.55 $92.43 $94.11 $92.44 $88.36
Three-way Collars
Volumes (MMBbls) 0.72 0.73 1.56 1.56 4.58 2.56
Call Price ($/Bbl) $103.13 $103.13 $103.65 $103.65 $103.48 $100.85
Put Price ($/Bbl) $90.82 $90.82 $90.03 $90.03 $90.28 $90.00
Short Put Price ($/Bbl) $73.13 $73.13 $78.15 $78.15 $76.56 $83.13
Natural Gas Q1 2015 Q2 2015 Q3 2015 Q4 2015 2015 2016
Swaps
Volumes (Bcf) 14.40 1.82 1.84 1.84 19.90 0.00
Price ($/Mcf) $4.62 $4.20 $4.20 $4.20 $4.51 NA
Collars
Volumes (Bcf) 0.25 0.25 0.25 0.25 1.01 0.00
Call Price ($/Mcf) $8.55 $8.55 $8.55 $8.55 $8.55 NA
Put Price ($/Mcf) $4.00 $4.00 $4.00 $4.00 $4.00 NA
Basis Swaps (PEPL)
Volumes (Bcf) 5.40 5.46 5.52 5.52 21.90 0.00
Swap Price ($/Mcf) ($0.273) ($0.273) ($0.273) ($0.273) ($0.273) NA
www.SandRidgeEnergy.com 27

28. 28
RESERVES PV10
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
Pro Forma 2013 Excluding Gulf of Mexico Proved Reserves*
SEC Pricing - $93.42 / $3.67
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
2013 RESERVE METRICS
Focused on the Mississippian Play
APPENDIX
www.SandRidgeEnergy.com 28

29. 29
-
20
40
60
80
100
120
140
160
180
200
-
50
100
150
200
250
300
350
CumulativeProduction(Mboe)
Avg.Boe/d
Type Curve Daily Avg. Rate Type Curve Cum Production
1 2 3 4 5 6 7 8 9 100
Years
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
2014 MISSISSIPPIAN PUD TYPE CURVE
380 MBoe, 48% Liquids
a) Represents decline from month 1 to month 13
b) Wet gas, wellhead volumes
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
www.SandRidgeEnergy.com 29
APPENDIX
As of 12/10/2014

30. 30
2014 OPERATIONAL GUIDANCE UPDATE
PRODUCTION
Oil (MMBbls) 10.8 - 11.2
Natural Gas Liquids (MMBbls) 3.6 - 3.7
Total Liquids (MMBbls) 14.4 - 14.9
Natural Gas (Bcf) 83.5 - 84.8
Total (MMBoe) 28.3 - 29.0
CAPITAL EXPENDITURES ($ in millions)
Exploration and Production $1,275
Land and Seismic 170
Total Exploration and Production $1,445
Oil Field Services 15
Electrical/Midstream 40
General Corporate 50
Total Capital Expenditures (excl. A&D) $1,550
EBITDA from Oilfield Services
and Other ($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) $2.60
NGLs (realized % of WTI) 36%
Gas (differential below Henry Hub) $0.65
COSTS PER BOE
Lifting $11.15 - $13.15
Production Taxes 1.10 - 1.20
DD&A – oil & gas 15.00 - 16.75
DD&A – other 2.10 - 2.30
Total DD&A $17.10 - $19.05
G&A – cash 3.35 – 3.55
G&A – stock 0.60 - 0.70
Total G&A $3.95 - $4.25
Corporate Tax Rate 0%
Deferral Rate 0%
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
www.SandRidgeEnergy.com 30
APPENDIX

31. 31
SANDRIDGE INVESTOR RELATIONS
123 Robert S. Kerr Avenue, Oklahoma City, OK 73102
investors@sandridgeenergy.com
www.SandRidgeEnergy.com
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.