Operator Name, Well Name/Number
1.
Geologic Formations
TVD of target
MD at TD:
9600
14172
Basin
Formation Depth (TVD) from KB
Surface Quaternary Fill
Rustler
Top of Salt
Lamar
Delaware Group
Bone Spring
2 nd
Bone Spring Lime
Wolfcamp
1200
1500
4000
4040
7000
9000
10600
Pilot hole depth 11500
Deepest expected fresh water: 487
Water/Mineral Bearing/
Target Zone?
Water
Water
Salt
Barren
Oil/Gas
Oil/Gas
Target Zone
Hazards*
Cisco
Canyon
Strawn
Atoka
Morrow
Barnett Shale
Woodford Shale
Devonian
Fusselman
Ellenburger
Granite Wash
*H2S, water flows, loss of circulation, abnormal pressures, etc.
Back Reef
Formation Depth (TVD) from KB
Water/Mineral Bearing/
Target Zone?
Surface Formation
Rustler
Top of Salt
Tansill
Yates
Seven Rivers
Queen
San Andres
Glorieta
Yeso
Abo
Wolfcamp
Cisco
10600
Hazards*
1
Drilling Plan

Operator Name, Well Name/Number
Canyon
Strawn
Atoka
Morrow
Barnett Shale
Woodford Shale
Devonian
Fusselman
Ellenburger
Granite Wash
*H2S, water flows, loss of circulation, abnormal pressures, etc.
Reef
Formation Depth (TVD) from KB)
Water/Mineral Bearing/
Target Zone?
Quaternary Alluvium Surface Water
Rustler
Top of Salt
Tansill
1200
1500
2100
Water
Salt
Yates
Seven Rivers
Capitan Reef
Delaware Group
Bone Spring
3 rd
Bone Spring Lime
Wolfcamp
Cisco
Canyon
Strawn
Atoka
Morrow
Barnett Shale
Woodford Shale
Devonian
2250
2650
2850
5400
7000
10000
10600
Oil
Water
Oil/Gas
Oil/Gas
Target Zone
Fusselman
Ellenburger
Granite Wash
*H2S, water flows, loss of circulation, abnormal pressures, etc.
2
Drilling Plan
Hazards*

Operator Name, Well Name/Number
2. Casing Program
Hole
Size
Casing Interval
From
17.5” 0
12.25” 0
12.25” 4000
8.75”
0
8.5” 9150
To
1230
4000
5150
9150
14172
Csg.
Size (lbs)
13.375” 54.5
9.625”
40
9.625” 40
5.5”
5.5”
Weight
17
17
Grade
J55
J55
P110
P110
Conn.
STC
LTC
BUTT
SF
Collapse
1.43
LTC 1.19
HCK55 LTC 1.35
1.56
1.56
BLM Minimum Safety Factor 1.125
SF
Burst
1.26
1.89
2.65
1.6
1.75
1
SF
Tension
2.59
2.1
2.24
2.63
1.91
1.6 Dry
1.8 Wet
All casing strings will be tested in accordance with Onshore Oil and Gas Order #2 III.B.1.h
Must have table for contingency casing
Is casing new? If used, attach certification as required in Onshore Order #1
Does casing meet API specifications? If no, attach casing specification sheet.
Is premium or uncommon casing planned? If yes attach casing specification sheet.
Does the above casing design meet or exceed BLM’s minimum standards? If not provide justification (loading assumptions, casing design criteria).
Y or N
Y
Y
N
Y
Will the intermediate pipe be kept at a minimum 1/3 fluid filled to avoid approaching
the collapse pressure rating of the casing?
Is well located within Capitan Reef?
If yes, does production casing cement tie back a minimum of 50’ above the Reef?
Is well within the designated 4 string boundary.
Is well located in R-111-P and SOPA?
Is well located in SOPA but not in R-111-P?
If yes, are the first 2 strings cemented to surface and 3 rd string cement tied back
500’ into previous casing?
If yes, are the first three strings cemented to surface?
Is 2 nd
string set 100’ to 600’ below the base of salt?
Is well located in high Cave/Karst?
If yes, are there two strings cemented to surface?
(For 2 string wells) If yes, is there a contingency casing if lost circulation occurs?
Is well located in critical Cave/Karst?
If yes, are there three strings cemented to surface?
3
Drilling Plan

Operator Name, Well Name/Number
3. Cementing Program
Casing # Sks Wt. lb/ gal
Surf.
Inter.
Prod.
600
300
1100
200
1100
200
375
400
1300
400
13.5
14.8
12.7
14.8
12.7
14.8
10.8
11.8
11.2
14.2
Yld ft3/ sack
1.73
1.34
2.22
1.32
2.22
1.32
3.68
2.38
2.21
1.28
H
2
0 gal/ sk
8
8
8
8
8
8
8
8
13
8
500#
Comp.
Strength
(hours)
10
8
15
11
11
6
22
10
25
7.5
Slurry Description
Lead: Class C + 4.0% Bentonite + 0.6% CD-32 +
0.5% CaCl2 +0.25lb/sk Cello-Flake
Tail: Class C + 0.005pps Static Free + 1% CaCl2 +
0.25 pps CelloFlake + 0.005 gps FP-6L
1 st stage Lead: Class C + 1.50% R-3 + 0.25 lb/sk
Cello-Flake + 2.0% Sodium Metasilicate + 10%10 salt
+ 0.005 lb/sk Static Free
1 st stage Tail: Class C + 0.25 lb/sk Cello Flake + 0.005 lb/sk Static Free
DV/ ECP Tool 3100’
2 nd stage Lead: Class C + 1.50% R-3 + 0.25 lb/sk
Cello-Flake + 2.0% Sodium Metasilicate + 10%10 salt
+ 0.005 lb/sk Static Free
2 nd stage Tail: Class C + 0.25 lb/sk Cello Flake +
0.005 lb/sk Static Free
1 st Lead: 60:40:0 Class C + 15.00 lb/sk BA-90 +
4.00% MPS-5 + 3.00% SMS + 5.00% A-10 + 1.00%
BA-10A + 0.80% ASA-301 + 2.90% R-21 + 8.00 lb/sk
LCM-1 + 0.005 lb/sk Static Free
1 st Tail: 50:50:2 Class H + 0.65% FL-52 + 0.20% CD-
32 + 0.15% SMS +2.00% Salt + 0.10% R-3 + 0.005 lb/sk Static Free
DV/ ECP Tool
5500’
2 nd stage Lead: 60:40:0 Class C + 15.00 lb/sk BA-90 +
4.00% MPS-5 + 3.00% SMS + 5.00% A-10 + 1.00%
BA-10A + 0.80% ASA-301 + 2.90% R-21 + 8.00 lb/sk
LCM-1 + 0.005 lb/sk Static Free
2 nd stage Tail: 50:50:2 Class H + 0.65% FL-52 +
0.20% CD-32 + 0.15% SMS +2.00% Salt + 0.10% R-3
+ 0.005 lb/sk Static Free
DV tool depth(s) will be adjusted based on hole conditions and cement volumes will be adjusted proportionally. DV tool will be set a minimum of 50 feet below previous casing and a minimum of 200 feet above current shoe. Lab reports with the 500 psi compressive strength time for the cement will be onsite for review.
Casing String
Surface
Intermediate
Production
TOC
0’
0’
4650’
% Excess
50%
100%
100%
4
Drilling Plan

Operator Name, Well Name/Number
Include Pilot Hole Cementing specs:
Pilot hole depth 11500
KOP 9150
Plug top
9000
11000
Plug
Bottom
9600
11500
%
Excess
10
10
No.
Sacks
Wt. lb/gal
Yld ft3/sack
600 13.5 0.99
300 14.8 1.18
Water gal/sk
Slurry Description and
Cement Type
5 Class H
8 Class H
4. Pressure Control Equipment
A variance is requested for the use of a diverter on the surface casing. See attached for schematic.
BOP installed and tested before drilling which hole?
Size?
Min.
Required
WP
Type

Tested to:
Annular x 50% of working pressure
12-1/4” 13-5/8” 2M
Blind Ram
Pipe Ram
Double Ram
Other*
Annular
Blind Ram
Pipe Ram x x x
2M
50% testing pressure
8-3/4”
11”
3M
Double Ram
Other
*
Annular
3M
Blind Ram
Pipe Ram
Double Ram
Other
*
*Specify if additional ram is utilized.
BOP/BOPE will be tested by an independent service company to 250 psi low and the high pressure indicated above per Onshore Order 2 requirements. The System may be upgraded to a higher pressure but still tested to the working pressure listed in the table above. If the system is upgraded all the components installed will be functional and tested .
5
Drilling Plan

Operator Name, Well Name/Number
Pipe rams will be operationally checked each 24 hour period. Blind rams will be operationally checked on each trip out of the hole. These checks will be noted on the daily tour sheets. Other accessories to the BOP equipment will include a Kelly cock and floor safety valve (inside BOP) and choke lines and choke manifold. See attached schematics.
X Formation integrity test will be performed per Onshore Order #2.
On Exploratory wells or on that portion of any well approved for a 5M BOPE system or greater, a pressure integrity test of each casing shoe shall be performed. Will be tested in accordance with Onshore Oil and Gas Order #2 III.B.1.i.
A variance is requested for the use of a flexible choke line from the BOP to Choke
Manifold. See attached for specs and hydrostatic test chart.
Y /N Are anchors required by manufacturer?
A multibowl wellhead is being used. The BOP will be tested per Onshore Order #2 after installation on the surface casing which will cover testing requirements for a maximum of
30 days. If any seal subject to test pressure is broken the system must be tested.

Provide description here
See attached schematic.
5. Mud Program
Depth Type Weight (ppg) Viscosity Water Loss
From
0
To
Surf. shoe FW Gel 8.6-8.8 28-34 N/C
Surf csg
Int shoe
Int shoe
TD
Saturated Brine 10.0-10.2
Cut Brine 8.5-9.3
28-34
28-34
N/C
N/C
Sufficient mud materials to maintain mud properties and meet minimum lost circulation and weight increase requirements will be kept on location at all times.
What will be used to monitor the loss or gain of fluid?
PVT/Pason/Visual Monitoring
6
Drilling Plan

Operator Name, Well Name/Number
6. Logging and Testing Procedures
Logging, Coring and Testing. x Will run GR/CNL fromTD to surface (horizontal well – vertical portion of hole). Stated logs run will be in the Completion Report and submitted to the BLM.
No Logs are planned based on well control or offset log information.
Drill stem test? If yes, explain
Coring? If yes, explain
Additional logs planned
X Resistivity
X Density
X CBL
X Mud log
PEX
Interval
Int. shoe to KOP
Int. shoe to KOP
Production casing
Intermediate shoe to TD
7. Drilling Conditions
Condition
BH Pressure at deepest TVD
Specify what type and where?
3400 psi
Abnormal Temperature Yes/No
Mitigation measure for abnormal conditions. Describe. Lost circulation material/sweeps/mud scavengers.
Hydrogen Sulfide (H2S) monitors will be installed prior to drilling out the surface shoe. If H2S is detected in concentrations greater than 100 ppm, the operator will comply with the provisions of Onshore Oil and Gas Order #6. If Hydrogen Sulfide is encountered, measured values and formations will be provided to the BLM.
H2S is present
H2S Plan attached
8. Other facets of operation
Will the well be drilled with a walking/skidding operation? If yes, describe.
Will more than one drilling rig be used for drilling operations? If yes, describe.
Attachments
___ Directional Plan
___ Other, describe
Yes/No
7
Drilling Plan