1. Corporate
Update
July 2013

2. 2
Forward-looking Statements
This presentation contains projections and
other forward-looking statements within the
meaning of Section 27A of the U.S. Securities
Act of 1933 and Section 21E of the U.S.
Securities Exchange Act of 1934. These
projections and statements reflect the
Company’s current views with respect to
future events and financial performance. No
assurances can be given, however, that these
events will occur or that these projections will
be achieved, and actual results could differ
materially from those projected as a result of
certain factors. A discussion of these factors
is included in the Company’s periodic reports
filed with the U.S. Securities and Exchange
Commission.
Contact:
Karen Acierno
Director – Investor Relations
kacierno@cimarex.com
Mark Burford
VP – Capital Markets & Planning
Cimarex Energy Co.
1700 Lincoln Street, Suite 1800
Denver, CO 80203
303-295-3995

3. Corporate Profile
NYSE: XEC
Shares outstanding………… 86.6 MM Proved reserves3
…………….. 2.3 Tcfe
Market cap1
……………………...… $5.7 B % Natural gas…………………… 55%
Long-term debt 2
…………….. $0.9 B % Proved developed………… 80%
Enterprise value……………… $6.6 B R/P Ratio……………………..…… 9.9x
Stockholders' equity2
……… $3.5 B Production4
……………..…….. 661 MMcfe/d
Debt/Cap2
…………………………… 20%
Quarterly dividend of $0.14/share
1 Share price as of June 21, 2013
2 As of March 31, 2013
3 As of December 31, 2012
4 For the three-months ended March 31, 2013
3

4. Cimarex Identity
• Grow through drilling
- Generate our own drilling inventory
• Portfolio approach
- Multiple basins and regions
- Gas, NGLs and oil
• Return driven
- Current focus on liquids-rich and oil-prone
projects
- Expanding Permian Basin operations
• Strong balance sheet
• Foster Cimarex culture
− Organic growth, idea-driven, analytical
4

5. 5
Core Operating Areas
2013 Capex - $1.5 billion
Q1 2013 Prod. 661 MMcfe/d
Mid-Continent
Permian
Gulf Coast
Mid-
Continent
31%
Permian
62%
Gulf Coast
5%

6. 6
What’s New
• Joint Development Agreement signed with Chevron
• Seeing solid drilling results from 2013 program
- On track to invest approximately $1.5 billion
- Production growth of 8-13%
• Active Delaware Basin program ($950 million)
- Drilling focused on Bone Spring and Wolfcamp formations
- Wolfcamp play continues to expand
- Culberson County emerging as a key multi-pay resource area
• Mid-Continent ($450 million)
- Cana-Woodford infill generating good returns
- Identify, test and evaluate new opportunities

7. 7
Permian Basin
Summary Statistics
Proved reserves (YE 12) 696.7 Bcfe
60% liquids; 99% proved developed
Production (Q1 2013) 275.1 MMcfe/d
71% liquids
Net acres (YE 12) 438,000
Capital Investment
2013E 2012A
E&D Capital (MM) $950 $889
Wells gross 175 182
net 115 122
Multiple Delaware Basin horizontal drilling projects with oil
and liquids-rich shale objectives
Permian

8. Delaware Basin Focus
8
• Multi-stacked formations
• Oil & liquids-rich targets
• 12-14 operated rigs
focused on Bone Spring
& Wolfcamp drilling
• Active Wolfcamp project
in Culberson County
• Emerging Wolfcamp in
Reeves County
• 2nd Bone Spring activity
transitioning to
Culberson County

9. Delaware Basin – Bone Spring
9
• 85-90 net Bone Spring
wells planned in 2013
• 2nd Bone Spring activity
increasing in Culberson
County – 2 rigs expected
to drill ~20 wells
• New Mexico 2nd/3rd Bone
Spring wells average ~640
Boe/d; 90% oil (30-day IP)
• Texas 3rd Bone Spring
wells average ~1,000
Boe/d; 80% oil (30-day IP)
Loving
Reeves
2012 Drilling:
107 gross (60 net) wells
• Hz Bone Spring wells

10. 59 T2
59 T1
60 T2
60 T1
6 5 4 3
10987
18 17 16 15
22212019
30 29 28 27
34333231
42 41 40 39
46454443
3 2 1
121110
15 14 13
242322
27 26 25
363534
39 38
37
484746
4
9
6 5 4 3
10987
18 17 16 15
22212019
30 29 28 27
34333231
42 41 40 39
46454443
3 2 1
121110
15 14 13
242322
27 26 25
363534
39 38 37
484746
34561234
6 5 4
3 2 1
121110987
18 17 16 15 14 13
242322212019
30 29 28 27 26 25
363534343231
42 41 40 39 38 37
484746454443
2 1
1211
14 13
2423
26 25
3635
38 37
4847
6
7
18
19
30
31
42
43
6 5 4 3 2 1
121110987
18 17 16 15 14 13
24232221
2019
30 29 28 27 26 25
363534333231
42 41 40 39
38 37
484746454443
2 1
1211
14 13
2423
26 25
3635
38 37
4847
43
42
31
30
19
18
7
6
2345612 1
2 1 6 5
4 3 34
2 51 26 51 6
12 79 10 11
8 9
8
11 12 7 81012 711
16 1517 16 14 18 17
18
13
13 14 13 17181514
21 2223 2424 19 20 21 232223
24 192019 20
28 2726 2530 29 28 27 26
25
25 30
26 30 29 29
33 34
31 32 35 3633 34 31 3236
35
35
36 31 32
2 14 36 5 5 42 1 3 26 1 6 5
10 1111 127 812 7 89 9 11 12 7 810
15 1414 17 1613 18 18 17 1613 14 13 18 1715
22 2323 2424 19 20
2023 24
21
1919 20 21 22
27 26 26 25
29 2826
29
30
30
25 25 29 2830 27
34 3536 31 35 36333235
3136 31 32 33 34 32
25S 27E25S 26E
26S 26E 26S 27E
New Mexico
Texas
Eddy County
Culberson County
Culberson County Joint Development Area
10
Before
59 T2
59 T1
60 T2
60 T1
6 5 4 3
10987
18 17 16 15
22212019
30 29 28 27
34333231
42 41 40 39
46454443
3 2 1
121110
15 14 13
242322
27 26 25
363534
39 38
37
484746
4
9
6 5 4 3
10987
18 17 16 15
22212019
30 29 28 27
34333231
42 41 40 39
46454443
3 2 1
121110
15 14 13
242322
27 26 25
363534
39 38 37
484746
34561234
6 5 4
3 2 1
121110987
18 17 16 15 14 13
242322212019
30 29 28 27 26 25
363534343231
42 41 40 39 38 37
484746454443
2 1
1211
14 13
2423
26 25
3635
38 37
4847
6
7
18
19
30
31
42
43
6 5 4 3 2 1
121110987
18 17 16 15 14 13
24232221
2019
30 29 28 27 26 25
363534333231
42 41 40 39
38 37
484746454443
2 1
1211
14 13
2423
26 25
3635
38 37
4847
43
42
31
30
19
18
7
6
2345612 1
2 1 6 5
4 3 34
2 51 26 51 6
12 79 10 11
8 9
8
11 12 7 81012 711
16 1517 16 14 18 17
18
13
13 14 13 17181514
21 2223 2424 19 20 21 232223
24 192019 20
28 2726 2530 29 28 27 26
25
25 30
26 30 29 29
33 34
31 32 35 3633 34 31 3236
35
35
36 31 32
2 14 36 5 5 42 1 3 26 1 6 5
10 1111 127 812 7 89 9 11 12 7 810
15 1414 17 1613 18 18 17 1613 14 13 18 1715
22 2323 2424 19 20
2023 24
21
1919 20 21 22
27 26 26 25
29 2826
29
30
30
25 25 29 2830 27
34 3536 31 35 36333235
3136 31 32 33 34 32
25S 27E25S 26E
26S 26E 26S 27E
New Mexico
Texas
Eddy County
Culberson County
After
• 50/50 partner with Chevron on 104k gross acres
• Cimarex operates
• Solves drilling /development challenges of checkerboard acreage
• Optimize field development and well locations
• Drill longer laterals

11. Culberson County Focus Area
11
• 100,000+ net acres
• 2013 main objectives:
2nd Bone Spring
• Two rigs; ~20 gross wells
• 4 wells to date with 30-day
average IP of over 900 Boe/d
Wolfcamp C&D
• Two rigs; 15-20 gross wells
• Drill to hold acreage
• 34 wells to date with 30-day
average IP of 6.4 MMcfe/d
59 T2
59 T1
60 T2
60 T1
6 5 4 3
10987
18 17 16 15
22212019
30 29 28 27
34333231
42 41 40 39
46454443
3 2 1
121110
15 14 13
242322
27 26 25
363534
39 38
37
484746
4
9
6 5 4 3
10987
18 17 16 15
22212019
30 29 28 27
34333231
42 41 40 39
46454443
3 2 1
121110
15 14 13
242322
27 26 25
363534
39 38 37
484746
34561234
6 5 4
3 2 1
121110987
18 17 16 15 14 13
242322212019
30 29 28 27 26 25
363534343231
42 41 40 39 38 37
484746454443
2 1
1211
14 13
2423
26 25
3635
38 37
4847
6
7
18
19
30
31
42
43
6 5 4 3 2 1
121110987
18 17 16 15 14 13
24232221
2019
30 29 28 27 26 25
363534333231
42 41 40 39
38 37
484746454443
2 1
1211
14 13
2423
26 25
3635
38 37
4847
43
42
31
30
19
18
7
6
2345612 1
2 1 6 5
4 3 34
2 51 26 51 6
12 79 10 11
8 9
8
11 12 7 81012 711
16 1517 16 14 18 17
18
13
13 14 13 17181514
21 2223 2424 19 20 21 232223
24 192019 20
28 2726 2530 29 28 27 26
25
25 30
26 30 29 29
33 34
31 32 35 3633 34 31 3236
35
35
36 31 32
2 14 36 5 5 42 1 3 26 1 6 5
10 1111 127 812 7 89 9 11 12 7 810
15 1414 17 1613 18 18 17 1613 14 13 18 1715
22 2323 2424 19 20
2023 24
21
1919 20 21 22
27 26 26 25
29 2826
29
30
30
25 25 29 2830 27
34 3536 31 35 36333235
3136 31 32 33 34 32
25S 27E25S 26E
26S 26E 26S 27E
New Mexico
Texas
Eddy County
Culberson County
HZ Bone Spring
HZ Wolfcamp

12. 12
Culberson County Focus Area Summary
• Multiple opportunities
• Five prospective horizons
• Very large Wolfcamp shale
resource potential
• Per zone Wolfcamp
development scenarios*
- Four wells/section: 1.7 - 2.1
Tcfe; $3.6bn of capital; 500
wells
- Eight wells/section: 3.4 - 4.1
Tcfe; $7.2bn of capital; 1000
wells
* Assumes EUR of 5.4Bcfe/well, drilling cost of
$7.2mm.

13. Rigging up in Culberson County
13

14. Culberson Infrastructure
14
• Significant infrastructure investment
- Salt water disposal (SWD)
- Electrical power
- Roads and bridge
- Triple Crown pipeline
• Triple Crown Pipeline
- 34 miles of 12” pipe
- Central compression
- Multiple sales points
• JT Processing Facility (Joule-Thomson)
- 50 MMcf/d capacity
- Residue gas sales to El Paso Permian
- NGLs trucked

15. Culberson County JT Plant
15

16. 16
Mid-Continent Region
Summary Statistics
Proved reserves (YE 12) 1,528.3 Bcfe
35% liquids; 71% proved developed
Production (Q1 2013) 360.6 MMcfe/d
34% liquids
Net acres (YE 12) 753,000
Capital Investment
2013E 2012A
E&D Capital ($ MM) $450 $673
Wells drilled - gross 145 167
net 55 69
Mid-Continent
Activity focused on Cana-Woodford infill development
and new idea generation

17. Cana-Woodford Shale
• Drilled or participated in
532 wells
• 120,000 net acres
- Avg. NRI’s ~81%
• Liquids-Rich Area
- Net acres: 75,000
- Gross pay: 100’ – 300’
- High oil and NGL
content
- Essentially all held by
production (HBP)
• Dry Gas
- Net acres: 45,000
- 22% HBP
XEC acreage
Liquids Rich
Dry Gas
17

18. Cana-Woodford –Infill Development
• Infill drilling in liquids-
rich core
• 2013E: 140 gross wells
- 100 non-operated
- 40 operated
• Two operated rigs by
mid-year
• Two-well pads drilling
nine wells per section
• Focus on drilling
program efficiencies
Operated well
Non-operated well
18
2012 Infill Row

19. Cana-Woodford Net Production
19
67
75
84
99 104
115
139
158 161
156
184
215
229
-
50
100
150
200
250
Q1A Q2A Q3A Q4A Q1A Q2A Q3A Q4A Q1A Q2A Q3A Q4A Q1A
2010A 2011A 2012A 2013E
MMcfe/d
Gas (MMcf/d) NGL (MMcfe/d) Oil (MMcfe/d)
Completion backlog
increased as result of
commencing infill
development

20. Cana-Woodford Summary
• Q1 13 production: 229 MMcfe/d
(42% increase over Q1 12)
• Significant resource potential:
Gas (MMcf/d) 139 61%
NGLs (b/d) 11,842 31%
Oil (b/d) 3,147 8%
Total (MMcfe/d) 229
Infill row looking east
Resource Potential
%
Liquid
Net
Acres
Net
Wells
Net
Capital
(Bcfe) ($ B)
Proved reserves (YE 2012) 1,130 36%
Risked upside (Core Liquids‐Rich) 3,300 46% 75,000 660 5.0
Total risked resource 4,430 44%

21. 21
Oil & Liquids-rich Projects fuel
Growth in Proved Reserves
0.3
0.6
0.8
1.0
1.2
1.3
1.2
1.3
‐
0.4
0.8
1.2
1.6
2.0
2.4
2009 2010 2011 2012
Tcfe
Oil & NGLs (Bcfe) Gas (Bcf)
23%
Liquids
77% Gas
33%
82% 77% 82% 80%
41% 45%
% Proved Developed
1.5
2.3

22. 22
Production Growth Driven by
Permian Basin and Mid-Continent
219
255
293
323
365
161
165
194
264
305
83
175
105
40
28
463
596 592
626
675‐705
‐
200
400
600
800
2009 2010 2011 2012 2013E
Mid‐Continent Permian Gulf Coast/Other
MMcfe/d

23. Summary Recap
• Well positioned for 2013 and beyond
- Primary focus on Permian projects
- Continued Cana development
- Generating new ideas
• Solid base of proved reserves and production
- 80% proved developed; 10-year reserve life
- Growing oil and NGL components
• Maintain strong balance sheet
- Debt to cap 20%; Debt to EBITDA < 1.0
• Long track record of profitable growth and
conservative use of leverage
23

24. 24
Appendix

25. 25
2013 Capital Investment Plan
Total Capital: $1.5 B By Region:
Permian Mid-Continent Gulf Coast/Other
• Invest $950 MM
• Drill approximately 175
gross/ 115 net wells
• 85-90 net Bone Spring,
15-20 net Wolfcamp,
remainder shallow and
other unconventional wells
• Invest $450 MM
• Cana development: $350 MM
• Approximately 145 gross/ 55
net wells
• Invest $100 MM
• Working new 3D data
• Approximately 6-9 net
wells

26. Hz Wolfcamp Type Curve*
26
72% 35% 21% 15% 13% 10% 9% 8% 7% 7%
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
0
1
2
3
4
5
6
7
0 1 2 3 4 5 6 7 8 9 10
Cumulative Production (Bcfe)
Daily Rate (Mmcfe)
End of Year
Daily Rate (Mmcfe/d)
Cumulative Prod. (Bcfe)
Annual
Decline Rate:
30‐day avg: 6.4 MMcfe/d EUR:
4.5‐5.5 Bcfe
(47% gas, 30% NGL & 23% oil)
*Culberson County well

27. Horizontal Wolfcamp Economics
27
17%
22%
28%
33%
39%
0%
10%
20%
30%
40%
50%
$75.00/$3.00 $80.00/$3.50 $85.00/$4.00 $90.00/$4.50 $95.00/$5.00
A-taxIRR
Realized Price - Oil ($/Bbl) & Gas ($/Mcf)
Forward strip IRR : 34%
( 5-20-13 )
Completed well cost $7.2 MM
NRI 75%
EUR 5.4 Bcfe
IP – 30 day average 6.4 MMcfe/d

28. 2013 Guidance
28
2013E
Q2 Full-Year
Production
Total Equivalent (Mmcfe/d) 667-692 675 - 705
% Liquids 50% 50%
Expenses ($/Mcfe):
Production $ 1.10 - 1.22
Transportation 0.27 - 0.32
DD&A and ARO accretion 2.40 - 2.55
General and administrative 0.22 - 0.28
Taxes other than income (% of oil and gas revenue) 6.0% - 6.5%
Capital Expenditures $1.5 billion
2013 Production, Unit Expense and Capital Guidance

29. Hedges
Oil
Weighted Average Price
Period Index Type Bbl/d Floor Ceiling Swap
Feb. - Dec. 2013 WTI Swap 6,000 NA NA $96.13
Feb. - Dec. 2013 WTI Collar 6,000 $85.00 $102.31 NA
12,000
Gas
Weighted Average Price
Period Index Type MMBTU/d Floor Ceiling
May - June 2013 PEPL Collar 30,000 $3.50 $4.50
July - Dec. 2014 PEPL Collar 80,000 $3.51 $4.57

30. Dividend
0.0%
0.2%
0.4%
0.6%
0.8%
1.0%
1.2%
1.4%
1.6%
0.00
0.02
0.04
0.06
0.08
0.10
0.12
0.14 Mar‐06
Jul‐06
Nov‐06
Mar‐07
Jul‐07
Nov‐07
Mar‐08
Jul‐08
Nov‐08
Mar‐09
Jul‐09
Nov‐09
Mar‐10
Jul‐10
Nov‐10
Mar‐11
Jul‐11
Nov‐11
Mar‐12
Jul‐12
Nov‐12
Mar‐13
Annual Yield
Quarterly Dividend (cents/share)
Quarterly Dividend Per Share Yield

31. Non-GAAP Reconciliation
($ in Millions) 2008 2009 2010 2011 2012
Net income (loss) (902)$ (312)$ 575$ 530$ 354$
Income tax expense (benefit) (529) (177) 339 312 207
Interest expense, net of capitalized 11 16 7 7 14
Depreciation, depletion and amortization 547 266 304 402 527
EBITDA (873) (206) 1,225 1,250 1,102
Asset retirement obligation expense 12 12 7 11 13
Impairment of oil and gas properties 2,243 791 - - -
Adjusted EBITDA 1,383$ 597$ 1,232$ 1,261$ 1,115$
Reconciliation of Net Income to EBITDA and Adjusted EBITDA
31

32. Non-GAAP Reconciliation
Reconciliation of cash flow from operations
32
2012
Net cash provided by operating activities $ 1,193
Change in operating assets
and liabilities (58)
Adjusted cash flow fromoperations $ 1,135
YE
(in millions)
2013
Long-termdebt $ 870
Stockholders' Equity 3,475
Total capitalization $ 4,345
Long-termdebt/total capitalization 20%
March 31,
(in millions)
Debt/Cap Calculation
2012
ProvedReserves adds (Bcfe)
Revisions of previous estimates (257.3)
Extensions & discoveries [C] 757.3
Purchase of reserves 0.2
Total adds [A] 500.2
Total capital $MM[B] 1,656$
All-sources F&D ($/Mcfe) [B]/[A] 3.31$
Drilling (excl. revisions) F&D ($/Mcfe) [B]/[C] 2.19$
Finding & development (F&D) cost