1. Pure Energy Consultants, LLC
East Resources Texas Creek Oriskany Sandstone Reservoir
Characterization: Update (Nov 18th, 2010)
Mike Cronin
716 479 2722
mbc5043@psu.edu
Zach Fidurko
716 378 5970
zmf5005@psu.edu
Matt Minemier
814-222-1854
mtm5097@psu.edu
Naser Saleh
814-441-1599
nbs5043@psu.edu

2. Recap: Development Plan
Graham #2
Volume of Recoverable Gas Per Block (SCF), North Up. Circle Area Denotes Drainage Area
(120 acres for Future Wells).
Blk = Wells in Place
Red = Phase 1 Wells: Data Acquisition and Production
Wht = Phase 2 Wells: Conditional on Phase 1, Part In-Field and Part Exploratory.

3. Overview
Accomplished:
-Finished Calculations for Vertical Well
Directional, Horizontal Well
- Cement calculations
- Mud design
- Casing design
- Bit selection

4. Predicting Fracture Gradient
• After PNG 450 Notes
Fracture Pressure (EQ. 5.25):
Po = Overburden Pressure (0.9 to 1.0 psi/ft) Equation obtained from John T.
Pr = Pore Pressure (Measurable with a formation tester) Dewan, “Essentials of Modern
α = Constant, approximately 0.5 Open-Hole Log Interpretation.”

5. Pore Pressure and Fracture Gradient
Pore Pressure and Fracture Pressure
Pressure (psia)
0 1000 2000 3000 4000 5000 6000 7000 8000
0
1000
2000
Pore Pressure
3000
Ben Eaton Fracture
Depth (TVD)
Hubbert & Willis Min
4000 Hubbert & Willis Max
EQ 5.25
Field Mud Pressure
5000
6000
7000
8000

6. Pore Pressure and Fracture Pressure EMW
Equivalent Mud Weight (PPG)
0 5 10 15 20 25
0
16-20”
1000
9-5/8”
2000
Air Till Pore Pressure
3000 Kickoff Ben Eaton Fracture
Point
Depth (TVD)
Hubbert & Willis
4000 Min 7”
Hubbert & Willis
Max
5000
6000
Fresh
7000
Water Mud
to TD
8000
Open Hole

7. X Coordinate
Graham 2 Delciotto 1 Delciotto 2 Shepard 1
2228000 2230000 2232000 2234000 2236000 2238000 2240000
6000
Generalizing Well Development:
6500 -Key Formations Identified
-Relate to KOP,
Maximum
7000
Inclination, Loss
Additives, TD, etc.
Depth (ft KB)
7500 Formation Top Bottom Thickness
Sand/Shale/Silstone 0 2640 2640
Shale 2640 6133 3493
Tully Limestone 6133 6262 129
8000 Hamilton Shale 6262 7248 986
Tully Limestone
Marcellus Shale 7248 7482 234
Hamilton Shale
Needmore Shale 7482 7533 51
Marcellus Shale
Onondaga Limestone 7533 7602 69
8500 Needmore Shale Oriskany SS 7602 7671 69
Onondaga Limestone Top: Graham # 2 Formation Tops from East Resources
Oriskany SS Completion Reports.
Oriskany TD
Left: Formation Tops in Texas Creek.
9000

8. Vertical Well
Vertical
0 500 1000 -TD = 7500’
0
-MD = 7500’
1000 Drilling Plan:
2000 Use Air and Hammer Bit down to ~6000’.
3000
Switch to Fresh Water Mud and PDC Bit to TD.
Mud up in preparation for Marcellus and
4000
Oriskany.
5000
6000
7000
8000

9. Directional
Directional Well
0 500 1000
0
Symmetric Build Hold
A and Drop ‘S’ Well
KOP = 1300’
1000 B -TD = 7500’
660’
R1 = 450’ -MD = 7661’
C α1 = 12.7o/100’
2000
LBC = 157’
-Horz. Departure = 933’
1320 ft
660’ TD = 7500’
3000 LCD = 2571’
KB
θ = 20o
D DO = 3870’
4000
E R2 = 450’
5000
α2 = 12.7o/100’ 40 acre plot, well head at
LDE = 157’ NW corner, target at
center.
6000
7000 TD = 7500’ / MD = 7661’
F
8000
Well trajectory, looking NE.

10. Directional Well
ROB1 = 12.7deg/100’ ROB2 = 12.7 deg/100’ Max Inclination = 8.65 deg
KOP = 1300’ DO = 2301’ TD = 7500’
Pore Pressure and Fracture Pressure EMW
0 5 10 15 20
Equivalent Mud Weight (PPG) 25
0
1000
2000
3000 Pore
Pressure
Depth (TVD)
Ben Eaton
4000
Fracture
Hubbert &
5000 Willis Min
Hubbert &
Willis Max
6000 Field Mud
Pressure
7000
8000

11. Horizontal Well
0 1000
Horizontal
2000 3000 4000
0 A
KOP = 6680’
1000
Horizontal Departure = 3820’
2000
Horizontal Length = 3000’
3000
4000
5000
6000
KOP = 6680’
B R1 = 820’
7000
α = 7o/100’
TD = 7500’
8000 C D MD = 10966’
L BC = 1286’ L CD = 3000’ Planar View of Well Trajectory.

12. Horizontal Well
ROB = 7deg/100’
KOP = 6680’
TD = 7500
Pore Pressure and Fracture Pressure EMW
0 5 10 15 20
Equivalent Mud Weight (PPG) 25
0
1000
2000
Pore
3000 Pressure
Ben Eaton
Depth (TVD)
Fracture
4000 Hubbert &
Willis Min
5000
6000
7000
8000

13. Mud Design
Depth (MD) Mud Weight (lb/g)
0-4716 air
4716 9 KOP
6497 9.1
6831 14.2
7165 13.5
7490 14.2
7490 14.3 Sting Run
7490 15.3
7508 15.5
7653 15.7
7673 15.8
East Resources Graham II data

14. Vertical
Depth (ft) Capacity (bbls)
TVD (7500) 526 Mud
Directional
Depth (ft) Capacity (bbls)
KOP (1300) 116.98
TD (7660) 552.1
Horizontal
Depth (ft) Capacity (bbls)
KOP (6680) 446
Landing Pt (7966) 493
TD (10966) 602 http://www.petroleumonline.com/content/overview.asp?mod=4
• Water based drilling mud – less expensive, Most common in Appalachian
• Lost circulation control – controls lost mud in high permeability sandstone,
prevents mud cakes (e.g. Nut shell)

15. Hammer Time
ITEM OD & #/ft. LENGTH ITEM OD & #/ft. LENGTH
Bit 12-1/4" 1.20 Bit 12-1/4" 1.00
Hammer 5.67
Hammer 5.65
Shocksub 12.18
Shock Sub 12.14
BHS 2.68
DC 8" 58.58 DC 8" 59.14
Bell Sub 2.76 Bell Sub 2.07
DC 6" 269.68 DC 6" 177.33
XO 1.24 XO 1.27

16. Bit Selection
• Reservoir formation
• Why chose a PDC bit?
• How effective is a PDC bit?

17. Economics Analysis
• The Economic advantage of a PDC bit.
– Save time and money.
– Has more uses.
– Help increase profit.
– AFE

18. Economic Analysis
Graham
ROP DelCiotto #1 days DelCiotto
ROP #2
Days n/a 0
n/a 1 Days
0
80.37037 2 0
4.189189 1 n/a 3 54.58537 1
2 n/a 4 54.58537 2
3 n/a 5
3
n/a 6
4 54.58537
n/a 7
59.72973 5 23.46218 8 4
6 n/a 54.58537
• Information taken from the 23.36402
n/a
9
54.58537
5
7
Daily reports for: 23.36402
n/a
10
78.10448
6
• DelCiotto #1 8 23.36402 11
n/a 78.10448 7
23.36402 12 8
• DelCiotto #2 9 n/a
n/a 13
78.10448
9
• DelCiotto #3 10 49.42529
n/a 14
78.10448
21.088 15
10
11 n/a 16 78.10448
n/a 17 11
n/a 18 78.10448
64.35135 12
n/a 19 12
18 20
78.10448
64.35135 4.5
3.142857 21
28.54936 13
13
n/a 78.10448
29.7027 14
n/a 22 28.54936 14
29.7027 15 6.333333 78.10448
8.740741 23 28.54936 15
6.785714
8.740741 24
6.785714
4.59375 16

19. Casing Details

20. Casing Strength
Casing Weight Diameter Burst (psi) Collapse (psi) Tensile (lb/ft)
36 # 9-5/8" 3520 2020 3636428
J-55 23 # 7" 5280 3270 3636428
10.5 # 4-1/2" 6081 4010 3636428
43.5 # 9-5/8" 8700 4419 830401
P110 26 # 7" 9955 5900 830401
13.5 # 4-1/2" 16275 10670 830401
Burst Collapse Tensile

21. Vertical
Casing Weight Capacity (bbls) Sacks
9-5/8" 43.5 # 69.72 334 Cement
7" 26 # 169 559
Directional http://loga.la/haynesville-shale-news/?p=361
Casing Weight Capacity (bbls) Sacks
9-5/8" 43.5 # 77.097 370
7" 26 # 73.01 350.4
Horizontal
Casing Weight Capacity (bbls) Sacks
9-5/8" 43.5 # 69.72 334
7" 26 # 28.2 135.5
4-1/2" 13.5 # 195 937
• Class A cement for all casing strings
• Cement goes to surface for all strings
• Pump 50% excess to account for fluid lost
• Common Additives:
• Bentonite- Increases viscosity, lowers slurry density, decreases cost
• Cement retarder- Reduces cement setting time (Calcium lignosulfonate)
• Lost circulation- Prevents loss of cement into formation
• Yield is 1.17 cuft/sack