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RECEIVED: January 27, 2014
STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES
DIVISION OF OIL, GAS AND MINING
APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER
ULT 12-5-4-2E
2. TYPE OF WORK
DRILL NEW WELL REENTER P&A WELL DEEPEN WELL 3. FIELD OR WILDCAT
LELAND BENCH
4. TYPE OF WELLOil Well Coalbed Methane Well: NO
5. UNIT or COMMUNITIZATION AGREEMENT NAME
6. NAME OF OPERATORCRESCENT POINT ENERGY U.S. CORP
7. OPERATOR PHONE720 880-3621
8. ADDRESS OF OPERATOR555 17th Street, Suite 750, Denver, CO, 80202
9. OPERATOR [email protected]
10. MINERAL LEASE NUMBER(FEDERAL, INDIAN, OR STATE)
FEE
11. MINERAL OWNERSHIP
FEDERAL INDIAN STATE FEE 12. SURFACE OWNERSHIP
FEDERAL INDIAN STATE FEE
13. NAME OF SURFACE OWNER (if box 12 = 'fee')Golbert Maggs
14. SURFACE OWNER PHONE (if box 12 = 'fee')321-917-4999
15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee')230 Park Avenue, ,
16. SURFACE OWNER E-MAIL (if box 12 = 'fee')
17. INDIAN ALLOTTEE OR TRIBE NAME(if box 12 = 'INDIAN')
18. INTEND TO COMMINGLE PRODUCTION FROMMULTIPLE FORMATIONS
YES (Submit Commingling Application) NO
19. SLANT
VERTICAL DIRECTIONAL HORIZONTAL
20. LOCATION OF WELL FOOTAGES QTR-QTR SECTION TOWNSHIP RANGE MERIDIAN
LOCATION AT SURFACE 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
Top of Uppermost Producing Zone 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
At Total Depth 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
21. COUNTYUINTAH
22. DISTANCE TO NEAREST LEASE LINE (Feet)663
23. NUMBER OF ACRES IN DRILLING UNIT40
25. DISTANCE TO NEAREST WELL IN SAME POOL(Applied For Drilling or Completed)
920
26. PROPOSED DEPTHMD: 8006 TVD: 8006
27. ELEVATION - GROUND LEVEL
5063
28. BOND NUMBER
LPM9080271
29. SOURCE OF DRILLING WATER /WATER RIGHTS APPROVAL NUMBER IF APPLICABLE
437478
Hole, Casing, and Cement Information
String Hole Size Casing Size Length Weight Grade & Thread Max Mud Wt. Cement Sacks Yield Weight
Cond 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0
Surf 12.25 8.625 0 - 1000 24.0 J-55 ST&C 8.3 Class G 450 1.15 15.8
Prod 7.875 5.5 0 - 8006 17.0 N-80 LT&C 10.0 Light (Hibond) 300 3.66 10.5
Class G 150 2.95 11.0
Class G 450 1.65 13.0
ATTACHMENTS
VERIFY THE FOLLOWING ARE ATTACHED IN ACCORDANCE WITH THE UTAH OIL AND GAS CONSERVATION GENERAL RULES
WELL PLAT OR MAP PREPARED BY LICENSED SURVEYOR OR ENGINEER COMPLETE DRILLING PLAN
AFFIDAVIT OF STATUS OF SURFACE OWNER AGREEMENT (IF FEE SURFACE) FORM 5. IF OPERATOR IS OTHER THAN THE LEASE OWNER
DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLY OR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP
NAME Lauren MacMillan TITLE Regulatory Specialist PHONE 303 382-6787
SIGNATURE DATE 10/25/2013 EMAIL [email protected]
API NUMBER ASSIGNED
43047540820000
Permit Manager
APPROVAL
FORM 3
AMENDED REPORT
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
FORM 3STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING
APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER12-5-4-2E
2. TYPE OF WORK 3. FIELD OR WILDCATDRILLNEWWELL REENTER P&AWELL DEEPEN WELLI LELANDBENCH
4. TYPE OF WELL 5. UNIT or COMMUNITIZATION AGREEMENT NAMEOil Well Coalbed Methane Well: NO
6. NAME OF OPERATOR 7. OPERATOR PHONECRESCENT POINT ENERGY U.S. CORP 720 880-3621
8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL555 17th Street, Suite 750, Denver, CO, 80202 [email protected]
10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORSTATEFEE FEDERAL INDIANISTATE FEE FEDERAL INDIAN STATE FEEI
13. NAME OF SURFACE OWNER (if box 12 = 'fee') 14. SURFACE OWNER PHONE (if box 12 = 'fee')Golbert Maggs 321-917-4999
15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee') 16. SURFACE OWNER E-MAIL (if box 12 = 'fee')230 Park Avenue, ,
17. INDIAN ALLOTTEE OR TRIBE NAME 18. INTEND TO COMMINGLE PRODUCTION FROM 19. SLANT
(if box 12 = 'INDIAN')MULTIPLE FORMATIONS
YES (Submit Commingling Application) NO VERTICAL DIRECTIONAL HORIZONTAL
20. LOCATION OF WELL FOOTAGES QTR-QTR SECTION TOWNSHIP RANGE MERIDIAN
LOCATION AT SURFACE 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
Top of Uppermost Producing Zone 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
At Total Depth 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITUINTAH 663 40
25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 8006 TVD: 8006
920
27. ELEVATION - GROUND LEVEL 28. BOND NUMBER 29. SOURCE OF DRILLING WATERIWATER RIGHTS APPROVAL NUMBER IF APPLICABLE
5063 LPM9080271 437478
Hole, Casing, and Cement Information
String Hole Size Casing Size Length Weight Grade & Thread Max Mud Wt. Cement Sacks Yield Weight
Cond 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0
Surf 12.25 8.625 0 - 1000 24.0 J-55 ST&C 8.3 Class G 450 1.15 15.8
Prod 7.875 5.5 0 - 8006 17.0 N-80 LT&C 10.0 Light (Hibond) 300 3.66 10.5
Class G 150 2.95 11.0
Class G 450 1.65 13.0
ATTACHMENTS
VERIFY THE FOLLOWING ARE ATTACHED IN ACCORDANCE WITH THE UTAH OIL AND GAS CONSERVATION GENERAL RULES
WELL PLATOR MAP PREPARED BY LICENSED SURVEYOR OR ENGINEER COMPLETE DRILLING PLAN
AFFIDAVIT OF STATUS OF SURFACE OWNER AGREEMENT(IF FEE SURFACE) FORM 5. IF OPERATOR IS OTHER THAN THE LEASE OWNER
DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLYOR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP
NAME Lauren MacMillan TITLE Regulatory Specialist PHONE 303 382-6787
SIGNATURE DATE 10/25/201 3 EMAIL [email protected]
API NUMBER ASSIGNED APPROVAL43047540820000
Permit Manager
RECEIVED: January 27,
API Well Number: 43047540820000
FORM 3STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING
APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER12-5-4-2E
2. TYPE OF WORK 3. FIELD OR WILDCATDRILLNEWWELL REENTER P&AWELL DEEPEN WELLI LELANDBENCH
4. TYPE OF WELL 5. UNIT or COMMUNITIZATION AGREEMENT NAMEOil Well Coalbed Methane Well: NO
6. NAME OF OPERATOR 7. OPERATOR PHONECRESCENT POINT ENERGY U.S. CORP 720 880-3621
8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL555 17th Street, Suite 750, Denver, CO, 80202 [email protected]
10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORSTATEFEE FEDERAL INDIANISTATE FEE FEDERAL INDIAN STATE FEEI
13. NAME OF SURFACE OWNER (if box 12 = 'fee') 14. SURFACE OWNER PHONE (if box 12 = 'fee')Golbert Maggs 321-917-4999
15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee') 16. SURFACE OWNER E-MAIL (if box 12 = 'fee')230 Park Avenue, ,
17. INDIAN ALLOTTEE OR TRIBE NAME 18. INTEND TO COMMINGLE PRODUCTION FROM 19. SLANT
(if box 12 = 'INDIAN')MULTIPLE FORMATIONS
YES (Submit Commingling Application) NO VERTICAL DIRECTIONAL HORIZONTAL
20. LOCATION OF WELL FOOTAGES QTR-QTR SECTION TOWNSHIP RANGE MERIDIAN
LOCATION AT SURFACE 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
Top of Uppermost Producing Zone 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
At Total Depth 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITUINTAH 663 40
25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 8006 TVD: 8006
920
27. ELEVATION - GROUND LEVEL 28. BOND NUMBER 29. SOURCE OF DRILLING WATERIWATER RIGHTS APPROVAL NUMBER IF APPLICABLE
5063 LPM9080271 437478
Hole, Casing, and Cement Information
String Hole Size Casing Size Length Weight Grade & Thread Max Mud Wt. Cement Sacks Yield Weight
Cond 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0
Surf 12.25 8.625 0 - 1000 24.0 J-55 ST&C 8.3 Class G 450 1.15 15.8
Prod 7.875 5.5 0 - 8006 17.0 N-80 LT&C 10.0 Light (Hibond) 300 3.66 10.5
Class G 150 2.95 11.0
Class G 450 1.65 13.0
ATTACHMENTS
VERIFY THE FOLLOWING ARE ATTACHED IN ACCORDANCE WITH THE UTAH OIL AND GAS CONSERVATION GENERAL RULES
WELL PLATOR MAP PREPARED BY LICENSED SURVEYOR OR ENGINEER COMPLETE DRILLING PLAN
AFFIDAVIT OF STATUS OF SURFACE OWNER AGREEMENT(IF FEE SURFACE) FORM 5. IF OPERATOR IS OTHER THAN THE LEASE OWNER
DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLYOR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP
NAME Lauren MacMillan TITLE Regulatory Specialist PHONE 303 382-6787
SIGNATURE DATE 10/25/201 3 EMAIL [email protected]
API NUMBER ASSIGNED APPROVAL43047540820000
Permit Manager
RECEIVED: January 27,
API Well Number: 43047540820000
FORM 3STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING
APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER12-5-4-2E
2. TYPE OF WORK 3. FIELD OR WILDCATDRILLNEWWELL REENTER P&AWELL DEEPEN WELLI LELANDBENCH
4. TYPE OF WELL 5. UNIT or COMMUNITIZATION AGREEMENT NAMEOil Well Coalbed Methane Well: NO
6. NAME OF OPERATOR 7. OPERATOR PHONECRESCENT POINT ENERGY U.S. CORP 720 880-3621
8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL555 17th Street, Suite 750, Denver, CO, 80202 [email protected]
10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORSTATEFEE FEDERAL INDIANISTATE FEE FEDERAL INDIAN STATE FEEI
13. NAME OF SURFACE OWNER (if box 12 = 'fee') 14. SURFACE OWNER PHONE (if box 12 = 'fee')Golbert Maggs 321-917-4999
15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee') 16. SURFACE OWNER E-MAIL (if box 12 = 'fee')230 Park Avenue, ,
17. INDIAN ALLOTTEE OR TRIBE NAME 18. INTEND TO COMMINGLE PRODUCTION FROM 19. SLANT
(if box 12 = 'INDIAN')MULTIPLE FORMATIONS
YES (Submit Commingling Application) NO VERTICAL DIRECTIONAL HORIZONTAL
20. LOCATION OF WELL FOOTAGES QTR-QTR SECTION TOWNSHIP RANGE MERIDIAN
LOCATION AT SURFACE 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
Top of Uppermost Producing Zone 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
At Total Depth 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITUINTAH 663 40
25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 8006 TVD: 8006
920
27. ELEVATION - GROUND LEVEL 28. BOND NUMBER 29. SOURCE OF DRILLING WATERIWATER RIGHTS APPROVAL NUMBER IF APPLICABLE
5063 LPM9080271 437478
Hole, Casing, and Cement Information
String Hole Size Casing Size Length Weight Grade & Thread Max Mud Wt. Cement Sacks Yield Weight
Cond 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0
Surf 12.25 8.625 0 - 1000 24.0 J-55 ST&C 8.3 Class G 450 1.15 15.8
Prod 7.875 5.5 0 - 8006 17.0 N-80 LT&C 10.0 Light (Hibond) 300 3.66 10.5
Class G 150 2.95 11.0
Class G 450 1.65 13.0
ATTACHMENTS
VERIFY THE FOLLOWING ARE ATTACHED IN ACCORDANCE WITH THE UTAH OIL AND GAS CONSERVATION GENERAL RULES
WELL PLATOR MAP PREPARED BY LICENSED SURVEYOR OR ENGINEER COMPLETE DRILLING PLAN
AFFIDAVIT OF STATUS OF SURFACE OWNER AGREEMENT(IF FEE SURFACE) FORM 5. IF OPERATOR IS OTHER THAN THE LEASE OWNER
DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLYOR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP
NAME Lauren MacMillan TITLE Regulatory Specialist PHONE 303 382-6787
SIGNATURE DATE 10/25/201 3 EMAIL [email protected]
API NUMBER ASSIGNED APPROVAL43047540820000
Permit Manager
RECEIVED: January 27,
API Well Number: 43047540820000
FORM 3STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING
APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER12-5-4-2E
2. TYPE OF WORK 3. FIELD OR WILDCATDRILLNEWWELL REENTER P&AWELL DEEPEN WELLI LELANDBENCH
4. TYPE OF WELL 5. UNIT or COMMUNITIZATION AGREEMENT NAMEOil Well Coalbed Methane Well: NO
6. NAME OF OPERATOR 7. OPERATOR PHONECRESCENT POINT ENERGY U.S. CORP 720 880-3621
8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL555 17th Street, Suite 750, Denver, CO, 80202 [email protected]
10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORSTATEFEE FEDERAL INDIANISTATE FEE FEDERAL INDIAN STATE FEEI
13. NAME OF SURFACE OWNER (if box 12 = 'fee') 14. SURFACE OWNER PHONE (if box 12 = 'fee')Golbert Maggs 321-917-4999
15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee') 16. SURFACE OWNER E-MAIL (if box 12 = 'fee')230 Park Avenue, ,
17. INDIAN ALLOTTEE OR TRIBE NAME 18. INTEND TO COMMINGLE PRODUCTION FROM 19. SLANT
(if box 12 = 'INDIAN')MULTIPLE FORMATIONS
YES (Submit Commingling Application) NO VERTICAL DIRECTIONAL HORIZONTAL
20. LOCATION OF WELL FOOTAGES QTR-QTR SECTION TOWNSHIP RANGE MERIDIAN
LOCATION AT SURFACE 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
Top of Uppermost Producing Zone 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
At Total Depth 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U
21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITUINTAH 663 40
25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 8006 TVD: 8006
920
27. ELEVATION - GROUND LEVEL 28. BOND NUMBER 29. SOURCE OF DRILLING WATERIWATER RIGHTS APPROVAL NUMBER IF APPLICABLE
5063 LPM9080271 437478
Hole, Casing, and Cement Information
String Hole Size Casing Size Length Weight Grade & Thread Max Mud Wt. Cement Sacks Yield Weight
Cond 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0
Surf 12.25 8.625 0 - 1000 24.0 J-55 ST&C 8.3 Class G 450 1.15 15.8
Prod 7.875 5.5 0 - 8006 17.0 N-80 LT&C 10.0 Light (Hibond) 300 3.66 10.5
Class G 150 2.95 11.0
Class G 450 1.65 13.0
ATTACHMENTS
VERIFY THE FOLLOWING ARE ATTACHED IN ACCORDANCE WITH THE UTAH OIL AND GAS CONSERVATION GENERAL RULES
WELL PLATOR MAP PREPARED BY LICENSED SURVEYOR OR ENGINEER COMPLETE DRILLING PLAN
AFFIDAVIT OF STATUS OF SURFACE OWNER AGREEMENT(IF FEE SURFACE) FORM 5. IF OPERATOR IS OTHER THAN THE LEASE OWNER
DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLYOR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP
NAME Lauren MacMillan TITLE Regulatory Specialist PHONE 303 382-6787
SIGNATURE DATE 10/25/201 3 EMAIL [email protected]
API NUMBER ASSIGNED APPROVAL43047540820000
Permit Manager
RECEIVED: January 27,
RECEIVED: October 25, 2013
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan 1
Crescent Point Energy U.S. Corp ULT 12-5-4-2E NW/SW of Section 5, T4S, R2E, USB&M SHL & BHL: 2091’ FSL & 948’ FWL Uintah County, Utah
DRILLING PLAN
1-2. Geologic Surface Formation and Estimated Tops of Important Geologic Markers
Formation Depth – TVD/MD
Uinta Surface
Upper Green River Marker 3,910’
Mahogany 4,399’
Garden Gulch (TGR3) 5,443’
Douglas Creek 6,303’
Black Shale 6,766’
Castle Peak 6,976’
Uteland 7,262’
Wasatch 7,406’
TD 8,006’
3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals Green River Formation (Oil) 3,910’ – 7,406’ Wasatch Formation (Oil) 7,406’ – 8,006’ Fresh water may be encountered in the Uinta Formation, but would not be expected below 350’. All
usable (>10,000 PPM TDS) water and prospectively valuable minerals (as described by DOGM at onsite) encountered during drilling will be recorded by depth and adequately protected.
All water shows and water bearing geologic units will be reported to the geologic and engineering staff of the DOGM prior to running the next string of casing or before plugging orders are requested. Usage of the State of Utah form Report of Water Encountered is acceptable, but not required. All water shows must be reported within one (1) business day after being encountered. Detected water flows shall be sampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM may request additional water samples for further analysis. The following information is requested for water shows and samples where applicable: Location & Sample Interval Date Sampled Flow Rate Temperature Hardness pH Water Classification (State of Utah) Dissolved Calcium (Ca) (mg/l) Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l) Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (CO3) (mg/l) Dissolved Bicarbonate (NaHCO3) (mg/l) Dissolved Chloride (Cl) (mg/l) Dissolved Sulfate (SO4) (mg/l) Dissolved Total Solids (TDS) (mg/l)
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Crescent Point Energy U.S. CorpULT12-5-4-2ENW/SW of Section 5, T4S, R2E, USB&MSHL& BHL:2091' FSL& 948' FWLUintah County, Utah
DRILLINGPLAN
1-2. Geologic Surface Formation and Estimated Tops of Important Geologic Markers
Formation Depth -TVD/MDUinta Surface
Upper Green River Marker 3,910'
Mahogany 4,399'
Garden Gulch (TGR3) 5,443'
Douglas Creek 6,303'
Black Shale 6,766'
Castle Peak 6,976'
Uteland 7,262'
Wasatch 7,406'
TD 8,006'
3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals
Green River Formation (Oil) 3,910'-7,406'Wasatch Formation (Oil) 7,406'-8,006'
Fresh water may be encountered in the Uinta Formation, but would not be expected below 350'. Allusable (>10,000PPM TDS) water and prospectively valuable minerals (as described by DOGM at onsite)encountered during drilling will be recorded by depth and adequately protected.
All water shows and water bearing geologic units will be reported to the geologic and engineering staff ofthe DOGM prior to running the next string of casing or before plugging orders are requested. Usage ofthe State of Utah form Report of Water Encountered is acceptable, but not required. Allwater showsmust be reported within one (1) business day after being encountered. Detected water flows shall besampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM mayrequest additional water samples for further analysis.
The following information is requested for water shows and samples where applicable:
Location & Sample Interval Date SampledFlow Rate TemperatureHardness pHWater Classification (State of Utah) Dissolved Calcium (Ca) (mg/l)Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l)Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (CO3)(mg/l)Dissolved Bicarbonate (NaHCOs) (mg/l) Dissolved Chloride (CI)(mg/l)Dissolved Sulfate (SO4) (mg/l) Dissolved Total Solids (TDS)(mg/l)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Crescent Point Energy U.S. CorpULT 12-5-4-2E
NW/SW of Section 5, T4S, R2E, USB&MSHL & BHL: 2091' FSL & 948' FWLUintah County, Utah
DRILLINGPLAN
1-2. Geologic Surface Formation and Estimated Tops of Important Geologic Markers
Formation Depth - TVD/MDUinta Surface
Upper Green River Marker 3,910'
Mahogany 4,399'
Garden Gulch (TGR3) 5,443'
Douglas Creek 6,303'
Black Shale 6,766'
Castle Peak 6,976'
Uteland 7,262'
Wasatch 7,406'
TD 8,006'
3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals
Green River Formation (Oil) 3,910'-7,406'Wasatch Formation (Oil) 7,406'-8,006'
Fresh water may be encountered in the Uinta Formation, but would not be expected below 350'. Allusable (>10,000PPM TDS)water and prospectively valuable minerals (as described by DOGM at onsite)encountered during drilling will be recorded by depth and adequately protected.
Allwater shows and water bearing geologic units will be reported to the geologic and engineering staff ofthe DOGM prior to running the next string of casing or before plugging orders are requested. Usage ofthe State of Utah form Report of Water Encountered is acceptable, but not required. All water showsmust be reported within one (1) business day after being encountered. Detected water flows shall besampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM mayrequest additional water samples for further analysis.
The following information is requested for water shows and samples where applicable:
Location & Sample Interval Date SampledFlow Rate TemperatureHardness pHWater Classification (State of Utah) Dissolved Calcium (Ca) (mg/l)Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l)Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (COs) (mg/l)Dissolved Bicarbonate (NaHCOs) (mg/l) Dissolved Chloride (CI) (mg/l)Dissolved Sulfate (SO4)(mg/l) Dissolved Total Solids (TDS)(mg/l)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Crescent Point Energy U.S. CorpULT 12-5-4-2E
NW/SW of Section 5, T4S, R2E, USB&MSHL & BHL: 2091' FSL & 948' FWLUintah County, Utah
DRILLINGPLAN
1-2. Geologic Surface Formation and Estimated Tops of Important Geologic Markers
Formation Depth - TVD/MDUinta Surface
Upper Green River Marker 3,910'
Mahogany 4,399'
Garden Gulch (TGR3) 5,443'
Douglas Creek 6,303'
Black Shale 6,766'
Castle Peak 6,976'
Uteland 7,262'
Wasatch 7,406'
TD 8,006'
3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals
Green River Formation (Oil) 3,910'-7,406'Wasatch Formation (Oil) 7,406'-8,006'
Fresh water may be encountered in the Uinta Formation, but would not be expected below 350'. Allusable (>10,000PPM TDS)water and prospectively valuable minerals (as described by DOGM at onsite)encountered during drilling will be recorded by depth and adequately protected.
Allwater shows and water bearing geologic units will be reported to the geologic and engineering staff ofthe DOGM prior to running the next string of casing or before plugging orders are requested. Usage ofthe State of Utah form Report of Water Encountered is acceptable, but not required. All water showsmust be reported within one (1) business day after being encountered. Detected water flows shall besampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM mayrequest additional water samples for further analysis.
The following information is requested for water shows and samples where applicable:
Location & Sample Interval Date SampledFlow Rate TemperatureHardness pHWater Classification (State of Utah) Dissolved Calcium (Ca) (mg/l)Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l)Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (COs) (mg/l)Dissolved Bicarbonate (NaHCOs) (mg/l) Dissolved Chloride (CI) (mg/l)Dissolved Sulfate (SO4)(mg/l) Dissolved Total Solids (TDS)(mg/l)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Crescent Point Energy U.S. CorpULT 12-5-4-2E
NW/SW of Section 5, T4S, R2E, USB&MSHL & BHL: 2091' FSL & 948' FWLUintah County, Utah
DRILLINGPLAN
1-2. Geologic Surface Formation and Estimated Tops of Important Geologic Markers
Formation Depth - TVD/MDUinta Surface
Upper Green River Marker 3,910'
Mahogany 4,399'
Garden Gulch (TGR3) 5,443'
Douglas Creek 6,303'
Black Shale 6,766'
Castle Peak 6,976'
Uteland 7,262'
Wasatch 7,406'
TD 8,006'
3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals
Green River Formation (Oil) 3,910'-7,406'Wasatch Formation (Oil) 7,406'-8,006'
Fresh water may be encountered in the Uinta Formation, but would not be expected below 350'. Allusable (>10,000PPM TDS)water and prospectively valuable minerals (as described by DOGM at onsite)encountered during drilling will be recorded by depth and adequately protected.
Allwater shows and water bearing geologic units will be reported to the geologic and engineering staff ofthe DOGM prior to running the next string of casing or before plugging orders are requested. Usage ofthe State of Utah form Report of Water Encountered is acceptable, but not required. All water showsmust be reported within one (1) business day after being encountered. Detected water flows shall besampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM mayrequest additional water samples for further analysis.
The following information is requested for water shows and samples where applicable:
Location & Sample Interval Date SampledFlow Rate TemperatureHardness pHWater Classification (State of Utah) Dissolved Calcium (Ca) (mg/l)Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l)Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (COs) (mg/l)Dissolved Bicarbonate (NaHCOs) (mg/l) Dissolved Chloride (CI) (mg/l)Dissolved Sulfate (SO4)(mg/l) Dissolved Total Solids (TDS)(mg/l)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
RECEIVED: October 25, 2013
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan 2
4. Proposed Casing & Cementing Program Casing Design:
Size Interval
Weight Grade Coupling Design Factors
Top Bottom Burst Collapse Tension
Conductor
0' 40' 65 H-40 STC
16" 1,640 670 439
Hole Size 24"
Surface casing
0' 1000' 24 J-55 STC
2,950 1,370 244,000
8-5/8"
Hole Size 12-1/4" 9.27 2.63 10.17
Prod casing
0' 8,006’ 17 E-80 LTC
7,740 6,280 348,000
5-1/2"
Hole Size 7-7/8" 2.62 1.30 2.20
Assumptions: 1. Surface casing max anticipated surface pressure (MASP) = Frac gradient – gas gradient 2. Production casing MASP (production mode) = Pore pressure – gas gradient 3. All collapse calculations assume fully evacuated casing w/gas gradient 4. All tension calculations assume air weight
Frac gradient at surface casing shoe = 10.0 ppg Pore pressure at surface casing shoe = 8.33 ppg Pore pressure at prod casing shoe = 8.33 ppg Gas gradient = 0.115 psi/ft
Minimum Safety Factors: Burst = 1.000 Collapse = 1.125 Tension = 1.800
All casing shall be new or, if used, inspected and tested. Used casing shall meet or exceed API standards for new casing.
All casing strings shall have a minimum of one (1) centralizer per joint on the bottom three joints.
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
4. Proposed Casing & Cementing Program
Casing Design:
Interval Design FactorsSize Weight Grade Coupling
Top Bottom Burst Collapse Tension
Conductor16" O' 40' 65 H-40 STC 1,640 670 439Hole Size 24"Surface casing 2,950 1,370 244,0008-5/8" O' 1000' 24 J-55 STCHole Size 12-1/4" 9.27 2.63 10.17Prod casing 7,740 6,280 348,0005-1/2" 0' 8,006' 17 E-80 LTC
Hole Size 7-7/8" 2.62 1.30 2.20
Assumptions:1. Surface casing max anticipated surface pressure (MASP) = Frac gradient -gas gradient2. Production casing MASP (production mode) = Pore pressure -gas gradient3. All collapse calculations assume fully evacuated casing w/gas gradient4. All tension calculations assume air weight
Frac gradient at surface casing shoe = 10.0 ppgPore pressure at surface casing shoe = 8.33 ppgPore pressure at prod casing shoe = 8.33 ppgGas gradient = 0.115 psi/ft
Minimum Safety Factors:Burst = 1.000Collapse = 1.125Tension = 1.800
All casing shall be new or, if used, inspected and tested. Used casing shall meet or exceed API standardsfor new casing.
All casing strings shall have a minimum of one (1) centralizer per joint on the bottom three joints.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
4. Proposed Casing & Cementing Program
Casing Design:
Interval Design FactorsSize Weight Grade Coupling
Top Bottom Burst Collapse Tension
Conductor16" 0' 40' 65 H-40 STC 1,640 670 439Hole Size 24"Surface casing 2,950 1,370 244,0008-5/8" 0' 1000' 24 J-55 STCHole Size 12-1/4" 9.27 2.63 10.17Prod casing 7,740 6,280 348,0005-1/2" 0' 8,006' 17 E-80 LTCHole Size 7-7/8" 2.62 1.30 2.20
Assumptions:1. Surface casing max anticipated surface pressure (MASP) = Frac gradient -gas gradient2. Production casing MASP (production mode) = Pore pressure -gas gradient3. All collapse calculations assume fully evacuated casing w/gas gradient4. All tension calculations assume air weight
Frac gradient at surface casing shoe = 10.0 ppgPore pressure at surface casing shoe = 8.33 ppgPore pressure at prod casing shoe = 8.33 ppgGas gradient = 0.115 psi/ft
Minimum Safety Factors:Burst = 1.000Collapse = 1.125Tension = 1.800
All casing shall be new or, if used, inspected and tested. Used casing shall meet or exceed API standardsfor new casing.
All casing strings shall have a minimum of one (1) centralizer per joint on the bottom three joints.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
4. Proposed Casing & Cementing Program
Casing Design:
Interval Design FactorsSize Weight Grade Coupling
Top Bottom Burst Collapse Tension
Conductor16" 0' 40' 65 H-40 STC 1,640 670 439Hole Size 24"Surface casing 2,950 1,370 244,0008-5/8" 0' 1000' 24 J-55 STCHole Size 12-1/4" 9.27 2.63 10.17Prod casing 7,740 6,280 348,0005-1/2" 0' 8,006' 17 E-80 LTCHole Size 7-7/8" 2.62 1.30 2.20
Assumptions:1. Surface casing max anticipated surface pressure (MASP) = Frac gradient -gas gradient2. Production casing MASP (production mode) = Pore pressure -gas gradient3. All collapse calculations assume fully evacuated casing w/gas gradient4. All tension calculations assume air weight
Frac gradient at surface casing shoe = 10.0 ppgPore pressure at surface casing shoe = 8.33 ppgPore pressure at prod casing shoe = 8.33 ppgGas gradient = 0.115 psi/ft
Minimum Safety Factors:Burst = 1.000Collapse = 1.125Tension = 1.800
All casing shall be new or, if used, inspected and tested. Used casing shall meet or exceed API standardsfor new casing.
All casing strings shall have a minimum of one (1) centralizer per joint on the bottom three joints.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
4. Proposed Casing & Cementing Program
Casing Design:
Interval Design FactorsSize Weight Grade Coupling
Top Bottom Burst Collapse Tension
Conductor16" 0' 40' 65 H-40 STC 1,640 670 439Hole Size 24"Surface casing 2,950 1,370 244,0008-5/8" 0' 1000' 24 J-55 STCHole Size 12-1/4" 9.27 2.63 10.17Prod casing 7,740 6,280 348,0005-1/2" 0' 8,006' 17 E-80 LTCHole Size 7-7/8" 2.62 1.30 2.20
Assumptions:1. Surface casing max anticipated surface pressure (MASP) = Frac gradient -gas gradient2. Production casing MASP (production mode) = Pore pressure -gas gradient3. All collapse calculations assume fully evacuated casing w/gas gradient4. All tension calculations assume air weight
Frac gradient at surface casing shoe = 10.0 ppgPore pressure at surface casing shoe = 8.33 ppgPore pressure at prod casing shoe = 8.33 ppgGas gradient = 0.115 psi/ft
Minimum Safety Factors:Burst = 1.000Collapse = 1.125Tension = 1.800
All casing shall be new or, if used, inspected and tested. Used casing shall meet or exceed API standardsfor new casing.
All casing strings shall have a minimum of one (1) centralizer per joint on the bottom three joints.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
RECEIVED: October 25, 2013
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan 3
Cementing Design:
Job Fill Description Excess Sacks Weight Yield
(ppg) (ft3/sk)
Surface casing
1000' - surface Class V 2% chlorides 100% 450 15.8 1.15
Prod Lead 2
4500' to Surface
Hifill Class V 3% chlorides 45% in open-
hole 0% in Cased hole
300 10.5 3.66
Prod casing Lead
6500’ to 4500' Hifill Class V 3% chlorides 25% 150 11 2.95
Prod casing Tail
TD to 6500’ Class G 10% chlorides 15% 450 13 1.65
*Actual volume pumped will have excess over gauge hole or caliper log if available - Compressive strength of tail cement: 500 psi @ 7 hours Waiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing of the BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6) hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded in the Driller’s Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.
The DOGM Roosevelt Field Office shall be notified, with sufficient lead time, in order to have a DOGM representative on location while running all casing strings and cementing.
The 8-5/8” surface casing shall in all cases be cemented back to surface. In the event that during the primary surface cementing operation the cement does not circulate to surface, or if the cement level should fall back more than 8 feet from surface, then a remedial surface cementing operation shall be performed to insure adequate isolation and stabilization of the surface casing.
The production casing cementing program shall be conducted as approved to protect and/or isolate all usable water zones, potentially productive zones, lost circulation zones, abnormally pressured zones, and any prospectively valuable deposits of minerals.
As a minimum, usable water zones shall be isolated and/or protected by having a cement top for the production casing at least 200 feet above the base of the usable water. If gilsonite is encountered while drilling, it shall be isolated and/or protected via the cementing program.
Top plugs shall be used to reduce contamination of cement by displacement fluid. A Tuned spacer will be used to prevent contamination of the lead cement by the drilling mud.
All casing strings below the conductor shall be pressure tested to 0.22 psi per foot of casing string length or to 1500 psi, whichever is greater, but not to exceed 70% of the minimum internal yield. If pressure declines more than 10% in 30 minutes, corrective action shall be taken.
A Form 9, “Sundry Notices and Reports on Wells” shall be filed with the DOGM within 30 days after the work is completed. This report must include the following information:
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Cementing Design:
Weight YieldJob Fill Description Excess Sacks
(ppg)(ft3/Sk)
Surface1000' - surface Class V 2% chlorides 100% 450 15.8 1.15
casing45% in open-
Prod 4500' toHifillClass V 3% chlorides hole 0% in 300 10.5 3.66
Lead 2 SurfaceCased hole
Prod casing6500' to 4500' Hifill Class V 3% chlorides 25% 150 11 2.95
Lead
Prod casingTD to 6500' Class G 10% chlorides 15% 450 13 1.65
Tail
*Actual volume pumped will have excess over gauge hole or caliper log if available- Compressive strength of tail cement: 500 psi @ 7 hoursWaiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing ofthe BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6)hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded inthe Driller's Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.
The DOGM Roosevelt Field Office shall be notified, with sufficient lead time, in order to have a DOGMrepresentative on location while running all casing strings and cementing.
The 8-5/8" surface casing shall in all cases be cemented back to surface. In the event that during theprimary surface cementing operation the cement does not circulate to surface, or if the cement levelshould fall back more than 8 feet from surface, then a remedial surface cementing operation shall beperformed to insure adequate isolation and stabilization of the surface casing.
The production casing cementing program shall be conducted as approved to protect and/or isolate allusable water zones, potentially productive zones, lost circulation zones, abnormally pressured zones, andany prospectively valuable deposits of minerals.
As a minimum, usable water zones shall be isolated and/or protected by having a cement top for theproduction casing at least 200 feet above the base of the usable water. If gilsonite is encountered whiledrilling, it shall be isolated and/or protected via the cementing program.
Top plugs shall be used to reduce contamination of cement by displacement fluid. A Tuned spacer will beused to prevent contamination of the lead cement by the drilling mud.
All casing strings below the conductor shall be pressure tested to 0.22 psi per foot of casing string lengthor to 1500 psi, whichever is greater, but not to exceed 70% of the minimum internal yield. If pressuredeclines more than 10% in 30 minutes, corrective action shall be taken.
A Form 9, "Sundry Notices and Reports on Wells" shall be filed with the DOGM within 30 days after thework is completed. This report must include the following information:
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Cementing Design:
Weight YieldJob Fill Description Excess Sacks
(ppg) (ft'/sk)
Surface1000' - surface Class V 2% chlorides 100% 450 15.8 1.15
casing45% in open-
Prod 4500' toHifillClass V 3% chlorides hole 0% in 300 10.5 3.66
Lead 2 SurfaceCased hole
Prod casing6500' to 4500' HifillClass V 3% chlorides 25% 150 11 2.95
Lead
Prod casingTD to 6500' Class G 10% chlorides 15% 450 13 1.65
Tail
*Actual volume pumped will have excess over gauge hole or caliper log if available- Compressive strength of tail cement: 500 psi @7 hoursWaiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing ofthe BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6)hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded inthe Driller's Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.
The DOGM Roosevelt Field Office shall be notified, with sufficient lead time, in order to have a DOGMrepresentative on location while running all casing strings and cementing.
The 8-5/8" surface casing shall in all cases be cemented back to surface. In the event that during theprimary surface cementing operation the cement does not circulate to surface, or if the cement levelshould fall back more than 8 feet from surface, then a remedial surface cementing operation shall beperformed to insure adequate isolation and stabilization of the surface casing.
The production casing cementing program shall be conducted as approved to protect and/or isolate allusable water zones, potentially productive zones, lost circulation zones, abnormally pressured zones, andany prospectively valuable deposits of minerals.
As a minimum, usable water zones shall be isolated and/or protected by having a cement top for theproduction casing at least 200 feet above the base of the usable water. Ifgilsonite is encountered whiledrilling, it shall be isolated and/or protected via the cementing program.
Top plugs shall be used to reduce contamination of cement by displacement fluid. A Tuned spacer will beused to prevent contamination of the lead cement by the drilling mud.
All casing strings below the conductor shall be pressure tested to 0.22 psi per foot of casing string lengthor to 1500 psi, whichever is greater, but not to exceed 70% of the minimum internal yield. If pressuredeclines more than 10% in 30 minutes, corrective action shall be taken.
A Form 9, "Sundry Notices and Reports on Wells" shall be filed with the DOGM within 30 days after thework is completed. This report must include the following information:
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Cementing Design:
Weight YieldJob Fill Description Excess Sacks
(ppg) (ft'/sk)
Surface1000' - surface Class V 2% chlorides 100% 450 15.8 1.15
casing45% in open-
Prod 4500' toHifillClass V 3% chlorides hole 0% in 300 10.5 3.66
Lead 2 SurfaceCased hole
Prod casing6500' to 4500' HifillClass V 3% chlorides 25% 150 11 2.95
Lead
Prod casingTD to 6500' Class G 10% chlorides 15% 450 13 1.65
Tail
*Actual volume pumped will have excess over gauge hole or caliper log if available- Compressive strength of tail cement: 500 psi @7 hoursWaiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing ofthe BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6)hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded inthe Driller's Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.
The DOGM Roosevelt Field Office shall be notified, with sufficient lead time, in order to have a DOGMrepresentative on location while running all casing strings and cementing.
The 8-5/8" surface casing shall in all cases be cemented back to surface. In the event that during theprimary surface cementing operation the cement does not circulate to surface, or if the cement levelshould fall back more than 8 feet from surface, then a remedial surface cementing operation shall beperformed to insure adequate isolation and stabilization of the surface casing.
The production casing cementing program shall be conducted as approved to protect and/or isolate allusable water zones, potentially productive zones, lost circulation zones, abnormally pressured zones, andany prospectively valuable deposits of minerals.
As a minimum, usable water zones shall be isolated and/or protected by having a cement top for theproduction casing at least 200 feet above the base of the usable water. Ifgilsonite is encountered whiledrilling, it shall be isolated and/or protected via the cementing program.
Top plugs shall be used to reduce contamination of cement by displacement fluid. A Tuned spacer will beused to prevent contamination of the lead cement by the drilling mud.
All casing strings below the conductor shall be pressure tested to 0.22 psi per foot of casing string lengthor to 1500 psi, whichever is greater, but not to exceed 70% of the minimum internal yield. If pressuredeclines more than 10% in 30 minutes, corrective action shall be taken.
A Form 9, "Sundry Notices and Reports on Wells" shall be filed with the DOGM within 30 days after thework is completed. This report must include the following information:
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Cementing Design:
Weight YieldJob Fill Description Excess Sacks
(ppg) (ft'/sk)
Surface1000' - surface Class V 2% chlorides 100% 450 15.8 1.15
casing45% in open-
Prod 4500' toHifillClass V 3% chlorides hole 0% in 300 10.5 3.66
Lead 2 SurfaceCased hole
Prod casing6500' to 4500' HifillClass V 3% chlorides 25% 150 11 2.95
Lead
Prod casingTD to 6500' Class G 10% chlorides 15% 450 13 1.65
Tail
*Actual volume pumped will have excess over gauge hole or caliper log if available- Compressive strength of tail cement: 500 psi @7 hoursWaiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing ofthe BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6)hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded inthe Driller's Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.
The DOGM Roosevelt Field Office shall be notified, with sufficient lead time, in order to have a DOGMrepresentative on location while running all casing strings and cementing.
The 8-5/8" surface casing shall in all cases be cemented back to surface. In the event that during theprimary surface cementing operation the cement does not circulate to surface, or if the cement levelshould fall back more than 8 feet from surface, then a remedial surface cementing operation shall beperformed to insure adequate isolation and stabilization of the surface casing.
The production casing cementing program shall be conducted as approved to protect and/or isolate allusable water zones, potentially productive zones, lost circulation zones, abnormally pressured zones, andany prospectively valuable deposits of minerals.
As a minimum, usable water zones shall be isolated and/or protected by having a cement top for theproduction casing at least 200 feet above the base of the usable water. Ifgilsonite is encountered whiledrilling, it shall be isolated and/or protected via the cementing program.
Top plugs shall be used to reduce contamination of cement by displacement fluid. A Tuned spacer will beused to prevent contamination of the lead cement by the drilling mud.
All casing strings below the conductor shall be pressure tested to 0.22 psi per foot of casing string lengthor to 1500 psi, whichever is greater, but not to exceed 70% of the minimum internal yield. If pressuredeclines more than 10% in 30 minutes, corrective action shall be taken.
A Form 9, "Sundry Notices and Reports on Wells" shall be filed with the DOGM within 30 days after thework is completed. This report must include the following information:
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
RECEIVED: October 25, 2013
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan 4
Setting of each string of casing showing the size, grade, weight of casing set, depth, amounts and type of cement used, whether cement circulated of the top of the cement behind the casing, depth of the cementing tools used, casing method and results, and the date of the work done. Spud date will be shown on the first reports submitted.
5. Drilling Fluids Program
The Conductor section (from 0’ to 40’) will be drilled by Auger and final depth determined by when the black shale is encountered with a minimum depth of 40’. The surface interval will then be drilled to ±1000’ with air/mist system. The air rig is equipped with a 6 ½” blooie line that is straight run to the reserve pit. A variance is in request for this operation. The request can be found in Section 12 of this plan. From ±1000’ to TD, a brine water system will be utilized. Clay inhibition and hole stability will be achieved with a polymer (DAP) additive; the reserve pit will be lined to address this additive. This brine water system will typically contain Total Dissolved Solids (TDS) of less than 3000 PPM. Anticipated mud weight is 9.5 lbs/gal. If it is necessary to control formation fluids or pressure, the system will be weighted with the addition of brine, and if pressure conditions warrant, barite and/or calcium carbonate will be used as a weighting agent. There will be enough weighting agent on location to increase the entire system to 11.0 ppg MW. No chromate additives will be used in the mud system on Federal and/or Indian lands without prior DOGM approval to ensure adequate protection of fresh water aquifers. No chemicals subject to reporting under SARA Title III in an amount equal to or greater than 10,000 pounds will be used, produced, stored, transported, or disposed of annually in association with the drilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as defined in 40 CFR 355, in threshold planning quantities, will be used, produced, stored, transported, or disposed of in association with the drilling, testing, or completing of this well. Hazardous substances specifically listed by the EPA as a hazardous waste or demonstrating characteristics of a hazardous waste will not be used in drilling, testing, or completion operations. Crescent Point Energy will visually monitor pit levels and flow from the well during drilling operations.
6. Minimum Specifications for Pressure Control A 3,000 psi BOP system or better will be used on this well. All equipment will be installed and tested per Onshore Order No. 2.
The configuration is as follows:
Float in drillstring
Inside BOP or safety valve
Safety valve with same pipe threading
Rotating Head below rotary table
Fillup line
11” Annular Preventer – rated to 3,000 psi minimum
11” bore, 4-1/2” pipe ram – rated to 3,000 psi minimum
11” bore, Blind Ram – rated to 3,000 psi minimum
11” bore Drilling Spool with 2 side outlets (Choke side at 3” minimum & Kill side at 2” minimum)
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Setting of each string of casing showing the size, grade, weight of casing set, depth, amounts andtype of cement used, whether cement circulated of the top of the cement behind the casing,depth of the cementing tools used, casing method and results, and the date of the work done.Spud date will be shown on the first reports submitted.
5. Drilling Fluids Program
The Conductor section (from O' to 40') will be drilled by Auger and final depth determined by when theblack shale is encountered with a minimum depth of 40'.
The surface interval will then be drilled to ±1000' with air/mist system. The air rig is equipped with a 6 ½"blooie line that is straight run to the reserve pit. A variance is in request for this operation. The requestcan be found in Section 12 of this plan.
From ±1000' to TD, a brine water system will be utilized. Clay inhibition and hole stability will be achievedwith a polymer (DAP) additive; the reserve pit will be lined to address this additive. This brine watersystem will typically contain Total Dissolved Solids (TDS)of less than 3000 PPM. Anticipated mud weightis 9.5 lbs/gal. If it is necessary to control formation fluids or pressure, the system will be weighted withthe addition of brine, and if pressure conditions warrant, barite and/or calcium carbonate will be used asa weighting agent. There will be enough weighting agent on location to increase the entire system to 11.0ppg MW.
No chromate additives will be used in the mud system on Federal and/or Indian lands without priorDOGM approval to ensure adequate protection of fresh water aquifers.
No chemicals subject to reporting under SARATitle Ill in an amount equal to or greater than 10,000pounds will be used, produced, stored, transported, or disposed of annually in association with thedrilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as definedin 40 CFR 355, in threshold planning quantities, will be used, produced, stored, transported, or disposedof in association with the drilling, testing, or completing of this well.
Hazardous substances specifically listed by the EPAas a hazardous waste or demonstrating characteristicsof a hazardous waste will not be used in drilling, testing, or completion operations.
Crescent Point Energy will visually monitor pit levels and flow from the well during drilling operations.
6. Minimum Specifications for Pressure Control
A 3,000 psi BOP system or better will be used on this well. All equipment will be installed and tested perOnshore Order No. 2.
The configuration is as follows:
• Float in drillstring• Inside BOP or safety valve• Safety valve with same pipe threading• Rotating Head below rotary table• Fillup line• 11" Annular Preventer - rated to 3,000 psi minimum• 11" bore, 4-1/2" pipe ram - rated to 3,000 psi minimum• 11" bore, Blind Ram - rated to 3,000 psi minimum• 11" bore Drilling Spool with 2 side outlets (Choke side at 3" minimum & Kill side at 2" minimum)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Setting of each string of casing showing the size, grade, weight of casing set, depth, amounts andtype of cement used, whether cement circulated of the top of the cement behind the casing,depth of the cementing tools used, casing method and results, and the date of the work done.Spud date will be shown on the first reports submitted.
5. Drilling Fluids Program
The Conductor section (from O' to 40') will be drilled by Auger and final depth determined by when theblack shale is encountered with a minimum depth of 40'.
The surface interval will then be drilled to ±1000' with air/mist system. The air rig is equipped with a 6 ½"blooie line that is straight run to the reserve pit. A variance is in request for this operation. The requestcan be found in Section 12 of this plan.
From ±1000' to TD, a brine water system will be utilized. Clay inhibition and hole stability will be achievedwith a polymer (DAP) additive; the reserve pit will be lined to address this additive. This brine watersystem will typically contain Total Dissolved Solids (TDS)of less than 3000 PPM. Anticipated mud weightis 9.5 lbs/gal. If it is necessary to control formation fluids or pressure, the system will be weighted withthe addition of brine, and if pressure conditions warrant, barite and/or calcium carbonate will be used asa weighting agent. There will be enough weighting agent on location to increase the entire system to 11.0ppg MW.
No chromate additives will be used in the mud system on Federal and/or Indian lands without priorDOGM approval to ensure adequate protection of fresh water aquifers.
No chemicals subject to reporting under SARATitle Ill in an amount equal to or greater than 10,000pounds will be used, produced, stored, transported, or disposed of annually in association with thedrilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as definedin 40 CFR355, in threshold planning quantities, will be used, produced, stored, transported, or disposedof in association with the drilling, testing, or completing of this well.
Hazardous substances specifically listed by the EPAas a hazardous waste or demonstrating characteristicsof a hazardous waste will not be used in drilling, testing, or completion operations.
Crescent Point Energy will visually monitor pit levels and flow from the well during drilling operations.
6. Minimum Specifications for Pressure Control
A 3,000 psi BOP system or better will be used on this well. All equipment will be installed and tested perOnshore Order No. 2.
The configuration is as follows:
• Float in drillstring• Inside BOP or safety valve• Safety valve with same pipe threading• Rotating Head below rotary table• Fillup line• 11" Annular Preventer - rated to 3,000 psi minimum• 11" bore, 4-1/2" pipe ram - rated to 3,000 psi minimum• 11" bore, Blind Ram - rated to 3,000 psi minimum• 11" bore Drilling Spool with 2 side outlets (Choke side at 3" minimum & Killside at 2" minimum)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Setting of each string of casing showing the size, grade, weight of casing set, depth, amounts andtype of cement used, whether cement circulated of the top of the cement behind the casing,depth of the cementing tools used, casing method and results, and the date of the work done.Spud date will be shown on the first reports submitted.
5. Drilling Fluids Program
The Conductor section (from O' to 40') will be drilled by Auger and final depth determined by when theblack shale is encountered with a minimum depth of 40'.
The surface interval will then be drilled to ±1000' with air/mist system. The air rig is equipped with a 6 ½"blooie line that is straight run to the reserve pit. A variance is in request for this operation. The requestcan be found in Section 12 of this plan.
From ±1000' to TD, a brine water system will be utilized. Clay inhibition and hole stability will be achievedwith a polymer (DAP) additive; the reserve pit will be lined to address this additive. This brine watersystem will typically contain Total Dissolved Solids (TDS)of less than 3000 PPM. Anticipated mud weightis 9.5 lbs/gal. If it is necessary to control formation fluids or pressure, the system will be weighted withthe addition of brine, and if pressure conditions warrant, barite and/or calcium carbonate will be used asa weighting agent. There will be enough weighting agent on location to increase the entire system to 11.0ppg MW.
No chromate additives will be used in the mud system on Federal and/or Indian lands without priorDOGM approval to ensure adequate protection of fresh water aquifers.
No chemicals subject to reporting under SARATitle Ill in an amount equal to or greater than 10,000pounds will be used, produced, stored, transported, or disposed of annually in association with thedrilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as definedin 40 CFR355, in threshold planning quantities, will be used, produced, stored, transported, or disposedof in association with the drilling, testing, or completing of this well.
Hazardous substances specifically listed by the EPAas a hazardous waste or demonstrating characteristicsof a hazardous waste will not be used in drilling, testing, or completion operations.
Crescent Point Energy will visually monitor pit levels and flow from the well during drilling operations.
6. Minimum Specifications for Pressure Control
A 3,000 psi BOP system or better will be used on this well. All equipment will be installed and tested perOnshore Order No. 2.
The configuration is as follows:
• Float in drillstring• Inside BOP or safety valve• Safety valve with same pipe threading• Rotating Head below rotary table• Fillup line• 11" Annular Preventer - rated to 3,000 psi minimum• 11" bore, 4-1/2" pipe ram - rated to 3,000 psi minimum• 11" bore, Blind Ram - rated to 3,000 psi minimum• 11" bore Drilling Spool with 2 side outlets (Choke side at 3" minimum & Killside at 2" minimum)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
Setting of each string of casing showing the size, grade, weight of casing set, depth, amounts andtype of cement used, whether cement circulated of the top of the cement behind the casing,depth of the cementing tools used, casing method and results, and the date of the work done.Spud date will be shown on the first reports submitted.
5. Drilling Fluids Program
The Conductor section (from O' to 40') will be drilled by Auger and final depth determined by when theblack shale is encountered with a minimum depth of 40'.
The surface interval will then be drilled to ±1000' with air/mist system. The air rig is equipped with a 6 ½"blooie line that is straight run to the reserve pit. A variance is in request for this operation. The requestcan be found in Section 12 of this plan.
From ±1000' to TD, a brine water system will be utilized. Clay inhibition and hole stability will be achievedwith a polymer (DAP) additive; the reserve pit will be lined to address this additive. This brine watersystem will typically contain Total Dissolved Solids (TDS)of less than 3000 PPM. Anticipated mud weightis 9.5 lbs/gal. If it is necessary to control formation fluids or pressure, the system will be weighted withthe addition of brine, and if pressure conditions warrant, barite and/or calcium carbonate will be used asa weighting agent. There will be enough weighting agent on location to increase the entire system to 11.0ppg MW.
No chromate additives will be used in the mud system on Federal and/or Indian lands without priorDOGM approval to ensure adequate protection of fresh water aquifers.
No chemicals subject to reporting under SARATitle Ill in an amount equal to or greater than 10,000pounds will be used, produced, stored, transported, or disposed of annually in association with thedrilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as definedin 40 CFR355, in threshold planning quantities, will be used, produced, stored, transported, or disposedof in association with the drilling, testing, or completing of this well.
Hazardous substances specifically listed by the EPAas a hazardous waste or demonstrating characteristicsof a hazardous waste will not be used in drilling, testing, or completion operations.
Crescent Point Energy will visually monitor pit levels and flow from the well during drilling operations.
6. Minimum Specifications for Pressure Control
A 3,000 psi BOP system or better will be used on this well. All equipment will be installed and tested perOnshore Order No. 2.
The configuration is as follows:
• Float in drillstring• Inside BOP or safety valve• Safety valve with same pipe threading• Rotating Head below rotary table• Fillup line• 11" Annular Preventer - rated to 3,000 psi minimum• 11" bore, 4-1/2" pipe ram - rated to 3,000 psi minimum• 11" bore, Blind Ram - rated to 3,000 psi minimum• 11" bore Drilling Spool with 2 side outlets (Choke side at 3" minimum & Killside at 2" minimum)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
RECEIVED: October 25, 2013
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan 5
o 2 Kill line valves at 2” minimum – one with a check valve o Kill line at 2” minimum o 2 Choke line valves at 3” minimum o Choke line at 3” minimum o 2 adjustable chokes on manifold o Pressure gauge on choke manifold
7. BOPE Test Criteria
A Function Test of the Ram BOP equipment shall be made every trip and annular preventer every week. All required BOP tests and/or drills shall be recorded in the Driller’s Report. Chart recorders will be used for all pressure tests. Test charts, with individual test results identified, shall be maintained on location while drilling and shall be made available to DOGM representatives upon request. At a minimum, the Annular preventer will be tested to 50% of its rating for ten minutes. All other equipment (Rams, valves, manifold) will be tested at 3,000 psi for 10 minutes with a test plug. If rams are to be changed for any reason post drillout, the rams will be tested to 70% of surface casing internal yield. At a minimum, the above pressure tests will be performed when such conditions exist:
BOP’s are initially installed
Whenever a seal subject to pressure test is broken
Following repairs to the BOPs
Every 30 days 8. Accumulator The Accumulator will have sufficient capacity to open the hydraulically-controlled choke line valve (HCR), close both rams and annular preventer as well maintain 200 psi above nitrogen precharge of the accumulator without use of accumulator pumps. The fluid reservoir volume will be double the usable volume of the accumulator system. The fluid level will be maintained per manufacturer’s specifications.
The BOP system will have two independent power sources to close both rams and annular preventer, while opening HCR. Nitrogen bottles will be one source and electric and/or air powered pumps will be the other. The accumulator precharge will be conducted every 6 months and maintained to be within the specifications of Onshore Order No. 2 A manual locking device or automatic locking device will be installed on both ram preventers and annular preventer. Remote controls will be readily accessible to the driller and be capable of closing all preventers. Main controls will be available to allow full functioning of all preventers and HCR.
9. Testing, Logging and Coring Programs
The logging program will consist of a Gamma Ray log from TD to base of surface casing @ +/- 1100’. A cement bond log will be run from PBTD to top of cement. No drill stem testing or coring is planned for this well.
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
o 2 Kill line valves at 2" minimum -one with a check valveo Kill line at 2" minimumo 2 Choke line valves at 3" minimumo Choke line at 3" minimumo 2 adjustable chokes on manifoldo Pressure gauge on choke manifold
7. BOPE Test Criteria
A Function Test of the Ram BOP equipment shall be made every trip and annular preventer every week.All required BOP tests and/or drills shall be recorded in the Driller's Report.
Chart recorders will be used for all pressure tests. Test charts, with individual test results identified, shallbe maintained on location while drilling and shall be made available to DOGM representatives uponrequest.
At a minimum, the Annular preventer will be tested to 50% of its rating for ten minutes. All otherequipment (Rams, valves, manifold) will be tested at 3,000 psi for 10 minutes with a test plug. If rams areto be changed for any reason post drillout, the rams will be tested to 70% of surface casing internal yield.
At a minimum, the above pressure tests will be performed when such conditions exist:• BOP's are initially installed• Whenever a seal subject to pressure test is broken• Following repairs to the BOPs• Every 30 days
8. Accumulator
The Accumulator will have sufficient capacity to open the hydraulically-controlled choke line valve (HCR),close both rams and annular preventer as well maintain 200 psi above nitrogen precharge of theaccumulator without use of accumulator pumps. The fluid reservoir volume will be double the usablevolume of the accumulator system. The fluid level will be maintained per manufacturer's specifications.
The BOP system will have two independent power sources to close both rams and annular preventer,while opening HCR. Nitrogen bottles will be one source and electric and/or air powered pumps will be theother.
The accumulator precharge will be conducted every 6 months and maintained to be within thespecifications of Onshore Order No. 2
A manual locking device or automatic locking device will be installed on both ram preventers and annularpreventer.
Remote controls will be readily accessible to the driller and be capable of closing all preventers. Maincontrols will be available to allow full functioning of all preventers and HCR.
9. Testing, Logging and Coring Programs
The logging program will consist of a Gamma Ray log from TD to base of surface casing @ +/-1100'. Acement bond log will be run from PBTD to top of cement. No drill stem testing or coring is planned forthis well.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
o 2 Killline valves at 2" minimum-one with a check valveo Killline at 2" minimumo 2 Choke line valves at 3" minimumo Choke line at 3" minimumo 2 adjustable chokes on manifoldo Pressure gauge on choke manifold
7. BOPETest Criteria
A Function Test of the Ram BOP equipment shall be made every trip and annular preventer every week.All required BOP tests and/or drills shall be recorded in the Driller's Report.
Chart recorders will be used for all pressure tests. Test charts, with individual test results identified, shallbe maintained on location while drilling and shall be made available to DOGM representatives uponrequest.
At a minimum, the Annular preventer will be tested to 50% of its rating for ten minutes. All otherequipment (Rams, valves, manifold) will be tested at 3,000 psi for 10 minutes with a test plug. If rams areto be changed for any reason post drillout, the rams will be tested to 70% of surface casing internal yield.
At a minimum, the above pressure tests will be performed when such conditions exist:• BOP's are initially installed• Whenever a seal subject to pressure test is broken• Following repairs to the BOPs• Every 30 days
8. Accumulator
The Accumulator will have sufficient capacity to open the hydraulically-controlled choke line valve (HCR),close both rams and annular preventer as well maintain 200 psi above nitrogen precharge of theaccumulator without use of accumulator pumps. The fluid reservoir volume will be double the usablevolume of the accumulator system. The fluid level will be maintained per manufacturer's specifications.
The BOP system will have two independent power sources to close both rams and annular preventer,while opening HCR.Nitrogen bottles will be one source and electric and/or air powered pumps will be theother.
The accumulator precharge will be conducted every 6 months and maintained to be within thespecifications of Onshore Order No. 2
A manual locking device or automatic locking device will be installed on both ram preventers and annularpreventer.
Remote controls will be readily accessible to the driller and be capable of closing all preventers. Maincontrols will be available to allow full functioning of all preventers and HCR.
9. Testing, Logging and Coring Programs
The logging program will consist of a Gamma Ray log from TD to base of surface casing @+/- 1100'. Acement bond log will be run from PBTDto top of cement. No drill stem testing or coring is planned forthis well.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
o 2 Killline valves at 2" minimum-one with a check valveo Killline at 2" minimumo 2 Choke line valves at 3" minimumo Choke line at 3" minimumo 2 adjustable chokes on manifoldo Pressure gauge on choke manifold
7. BOPETest Criteria
A Function Test of the Ram BOP equipment shall be made every trip and annular preventer every week.All required BOP tests and/or drills shall be recorded in the Driller's Report.
Chart recorders will be used for all pressure tests. Test charts, with individual test results identified, shallbe maintained on location while drilling and shall be made available to DOGM representatives uponrequest.
At a minimum, the Annular preventer will be tested to 50% of its rating for ten minutes. All otherequipment (Rams, valves, manifold) will be tested at 3,000 psi for 10 minutes with a test plug. If rams areto be changed for any reason post drillout, the rams will be tested to 70% of surface casing internal yield.
At a minimum, the above pressure tests will be performed when such conditions exist:• BOP's are initially installed• Whenever a seal subject to pressure test is broken• Following repairs to the BOPs• Every 30 days
8. Accumulator
The Accumulator will have sufficient capacity to open the hydraulically-controlled choke line valve (HCR),close both rams and annular preventer as well maintain 200 psi above nitrogen precharge of theaccumulator without use of accumulator pumps. The fluid reservoir volume will be double the usablevolume of the accumulator system. The fluid level will be maintained per manufacturer's specifications.
The BOP system will have two independent power sources to close both rams and annular preventer,while opening HCR.Nitrogen bottles will be one source and electric and/or air powered pumps will be theother.
The accumulator precharge will be conducted every 6 months and maintained to be within thespecifications of Onshore Order No. 2
A manual locking device or automatic locking device will be installed on both ram preventers and annularpreventer.
Remote controls will be readily accessible to the driller and be capable of closing all preventers. Maincontrols will be available to allow full functioning of all preventers and HCR.
9. Testing, Logging and Coring Programs
The logging program will consist of a Gamma Ray log from TD to base of surface casing @+/- 1100'. Acement bond log will be run from PBTDto top of cement. No drill stem testing or coring is planned forthis well.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
o 2 Killline valves at 2" minimum-one with a check valveo Killline at 2" minimumo 2 Choke line valves at 3" minimumo Choke line at 3" minimumo 2 adjustable chokes on manifoldo Pressure gauge on choke manifold
7. BOPETest Criteria
A Function Test of the Ram BOP equipment shall be made every trip and annular preventer every week.All required BOP tests and/or drills shall be recorded in the Driller's Report.
Chart recorders will be used for all pressure tests. Test charts, with individual test results identified, shallbe maintained on location while drilling and shall be made available to DOGM representatives uponrequest.
At a minimum, the Annular preventer will be tested to 50% of its rating for ten minutes. All otherequipment (Rams, valves, manifold) will be tested at 3,000 psi for 10 minutes with a test plug. If rams areto be changed for any reason post drillout, the rams will be tested to 70% of surface casing internal yield.
At a minimum, the above pressure tests will be performed when such conditions exist:• BOP's are initially installed• Whenever a seal subject to pressure test is broken• Following repairs to the BOPs• Every 30 days
8. Accumulator
The Accumulator will have sufficient capacity to open the hydraulically-controlled choke line valve (HCR),close both rams and annular preventer as well maintain 200 psi above nitrogen precharge of theaccumulator without use of accumulator pumps. The fluid reservoir volume will be double the usablevolume of the accumulator system. The fluid level will be maintained per manufacturer's specifications.
The BOP system will have two independent power sources to close both rams and annular preventer,while opening HCR.Nitrogen bottles will be one source and electric and/or air powered pumps will be theother.
The accumulator precharge will be conducted every 6 months and maintained to be within thespecifications of Onshore Order No. 2
A manual locking device or automatic locking device will be installed on both ram preventers and annularpreventer.
Remote controls will be readily accessible to the driller and be capable of closing all preventers. Maincontrols will be available to allow full functioning of all preventers and HCR.
9. Testing, Logging and Coring Programs
The logging program will consist of a Gamma Ray log from TD to base of surface casing @+/- 1100'. Acement bond log will be run from PBTDto top of cement. No drill stem testing or coring is planned forthis well.
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
RECEIVED: October 25, 2013
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan 6
10. Anticipated Abnormal Pressures or Temperature
No abnormal temperatures or pressures are anticipated. No hydrogen sulfide has been encountered or is known to exist from previous wells drilled to similar depths in this area.
Maximum anticipated bottomhole pressure will be approximately equal to total depth in feet multiplied by a 0.52 psi/ft gradient, and a maximum anticipated surface pressure will be approximately equal to the bottomhole pressure calculated minus the pressure of a partially evacuated hole calculated at a 0.22 psi/foot gradient.
11. Anticipated Starting Date and Duration of Operations
It is anticipated that drilling operations will commence as soon as possible following permit approval and will take approximately ten (10) days from spud to rig release and two weeks for completions.
12. Variances Requested from Onshore Order No. 2
1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head. 2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down. 3. The blooie line is not equipped with an automatic igniter or continuous pilot light. 4. The compressor is located on the rig itself and not 100 ft from the wellbore. 5. The requirement for an Formation Integrity Test (FIT) or a Leak Off Test (LOT)
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
10. Anticipated Abnormal Pressures or Temperature
No abnormal temperatures or pressures are anticipated. No hydrogen sulfide has been encountered or isknown to exist from previous wells drilled to similar depths in this area.
Maximum anticipated bottomhole pressure will be approximately equal to total depth in feet multipliedby a 0.52 psi/ft gradient, and a maximum anticipated surface pressure will be approximately equal to thebottomhole pressure calculated minus the pressure of a partially evacuated hole calculated at a 0.22psi/foot gradient.
11. Anticipated Starting Date and Duration of Operations
It is anticipated that drilling operations will commence as soon as possible following permit approval andwill take approximately ten (10) days from spud to rig release and two weeks for completions.
12. Variances Requested from Onshore Order No. 2
1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head.2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down.3. The blooie line is not equipped with an automatic igniter or continuous pilot light.4. The compressor is located on the rig itself and not 100 ft from the wellbore.5. The requirement for an Formation Integrity Test (FIT) or a Leak Off Test (LOT)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
10. Anticipated Abnormal Pressures or Temperature
No abnormal temperatures or pressures are anticipated. No hydrogen sulfide has been encountered or isknown to exist from previous wells drilled to similar depths in this area.
Maximum anticipated bottomhole pressure will be approximately equal to total depth in feet multipliedby a 0.52 psi/ft gradient, and a maximum anticipated surface pressure will be approximately equal to thebottomhole pressure calculated minus the pressure of a partially evacuated hole calculated at a 0.22psi/foot gradient.
11. Anticipated Starting Date and Duration of Operations
It is anticipated that drilling operations will commence as soon as possible following permit approval andwill take approximately ten (10) days from spud to rig release and two weeks for completions.
12. Variances Requested from Onshore Order No. 2
1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head.2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down.3. The blooie line is not equipped with an automatic igniter or continuous pilot light.4. The compressor is located on the rig itself and not 100 ft from the wellbore.5. The requirement for an Formation Integrity Test (FIT)or a Leak Off Test (LOT)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
10. Anticipated Abnormal Pressures or Temperature
No abnormal temperatures or pressures are anticipated. No hydrogen sulfide has been encountered or isknown to exist from previous wells drilled to similar depths in this area.
Maximum anticipated bottomhole pressure will be approximately equal to total depth in feet multipliedby a 0.52 psi/ft gradient, and a maximum anticipated surface pressure will be approximately equal to thebottomhole pressure calculated minus the pressure of a partially evacuated hole calculated at a 0.22psi/foot gradient.
11. Anticipated Starting Date and Duration of Operations
It is anticipated that drilling operations will commence as soon as possible following permit approval andwill take approximately ten (10) days from spud to rig release and two weeks for completions.
12. Variances Requested from Onshore Order No. 2
1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head.2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down.3. The blooie line is not equipped with an automatic igniter or continuous pilot light.4. The compressor is located on the rig itself and not 100 ft from the wellbore.5. The requirement for an Formation Integrity Test (FIT)or a Leak Off Test (LOT)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
API Well Number: 43047540820000
10. Anticipated Abnormal Pressures or Temperature
No abnormal temperatures or pressures are anticipated. No hydrogen sulfide has been encountered or isknown to exist from previous wells drilled to similar depths in this area.
Maximum anticipated bottomhole pressure will be approximately equal to total depth in feet multipliedby a 0.52 psi/ft gradient, and a maximum anticipated surface pressure will be approximately equal to thebottomhole pressure calculated minus the pressure of a partially evacuated hole calculated at a 0.22psi/foot gradient.
11. Anticipated Starting Date and Duration of Operations
It is anticipated that drilling operations will commence as soon as possible following permit approval andwill take approximately ten (10) days from spud to rig release and two weeks for completions.
12. Variances Requested from Onshore Order No. 2
1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head.2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down.3. The blooie line is not equipped with an automatic igniter or continuous pilot light.4. The compressor is located on the rig itself and not 100 ft from the wellbore.5. The requirement for an Formation Integrity Test (FIT)or a Leak Off Test (LOT)
Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
R. 2 E. N
S 88'20 45" w N 88'16'32" E N 88°33 14" E N 86 13 56" ES¾a 1321.02° 5TN 1324.56' AC 1308.99' 1308.66' AC
.. LOT 2 LOT 1
LOT 4 LOT 3 m 12-5-4-2EGMEDEWAHOM
SCALE 1" = 1000'
STNAk - - - - -
·¯
¯-- SM.2' - -
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATED AT THE SWCORNER SECTION 5, T4S, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
N 88 23'23" E 5 s2eo.44LONGITUDE (NAD 83)
STNd ----- .,
---·--- ,--- STN WEST 109.799299 DEG
1320.11 1320.11 1320.11 1320.11·
LATITUDE (NAD 27)
. oNORTH 40.162755 DEG.
948 LONGITUDE (MAD27)
ioWEST 109.798601 DEG.
NORTHING670851.36
STN --8 211 NJS610 ---
N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09
DATUMSPCS UTC (NAD 27)
STNiS 88'55'01" W STN 1326.92 STN 1334.24 STN 1320.17 SN
1331.78'1000 500 0 1000 2000
§URVEVOR'SSTATEMENT SCALE FEET
DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO, HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURtNG AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLY SHOWS THE LOCATIONOF ULT 12-5-4-2E AS STAKED ON THE G
LEGENDe WELL LOCATION 8262603O BOTTOM HOLE LOC. (APPROX) q.O CALCULATEDCORNERO FOUND MONUMENT UTAH PL 603--ÊÊÒ1A PREVIOUSLY FOUND MONUMENT
PIAT OF DRIEEEVG LOCATIONRIFFIN & ASSOCIATES, INC. FOR
panær6028 1414 ELNST, ROCKSPRINGS, WY82001 UTE ENERGYDRAWN:7/9/12- TCM SCALE: 1"= 1000' 2092 F/SL & 948'F NWSW, SECTION 5,
REVISED: NA DRG JOB No. 19386 T. 4 S., R. 2 E., U.S.MEXHIBIT f N
API Well Number: 43047540820000
R. 2 E. N
S 88'20 45" w N 88'16'32" E N 88°33 14" E N 86 13 56" ES¾a 1321.02° 5TN 1324.56' AC 1308.99' 1308.66' AC
.. LOT 2 LOT 1
LOT 4 LOT 3 m 12-5-4-2EGMEDEWAHOM
SCALE 1" = 1000'
STNAk - - - - -
·¯
¯-- SM.2' - -
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATED AT THE SWCORNER SECTION 5, T4S, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
N 88 23'23" E 5 s2eo.44LONGITUDE (NAD 83)
STNd ----- .,
---·--- ,--- STN WEST 109.799299 DEG
1320.11 1320.11 1320.11 1320.11·
LATITUDE (NAD 27)
. oNORTH 40.162755 DEG.
948 LONGITUDE (MAD27)
ioWEST 109.798601 DEG.
NORTHING670851.36
STN --8 211 NJS610 ---
N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09
DATUMSPCS UTC (NAD 27)
STNiS 88'55'01" W STN 1326.92 STN 1334.24 STN 1320.17 SN
1331.78'1000 500 0 1000 2000
§URVEVOR'SSTATEMENT SCALE FEET
DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO, HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURtNG AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLY SHOWS THE LOCATIONOF ULT 12-5-4-2E AS STAKED ON THE G
LEGENDe WELL LOCATION 8262603O BOTTOM HOLE LOC. (APPROX) q.O CALCULATEDCORNERO FOUND MONUMENT UTAH PL 603--ÊÊÒ1A PREVIOUSLY FOUND MONUMENT
PIAT OF DRIEEEVG LOCATIONRIFFIN & ASSOCIATES, INC. FOR
panær6028 1414 ELNST, ROCKSPRINGS, WY82001 UTE ENERGYDRAWN:7/9/12- TCM SCALE: 1"= 1000' 2092 F/SL & 948'F NWSW, SECTION 5,
REVISED: NA DRG JOB No. 19386 T. 4 S., R. 2 E., U.S.MEXHIBIT f N
API Well Number: 43047540820000
R. 2 E. N
S 88'20 45" w N 88'16'32" E N 88°33 14" E N 86 13 56" ES¾a 1321.02° 5TN 1324.56' AC 1308.99' 1308.66' AC
.. LOT 2 LOT 1
LOT 4 LOT 3 m 12-5-4-2EGMEDEWAHOM
SCALE 1" = 1000'
STNAk - - - - -
·¯
¯-- SM.2' - -
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATED AT THE SWCORNER SECTION 5, T4S, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
N 88 23'23" E 5 s2eo.44LONGITUDE (NAD 83)
STNd ----- .,
---·--- ,--- STN WEST 109.799299 DEG
1320.11 1320.11 1320.11 1320.11·
LATITUDE (NAD 27)
. oNORTH 40.162755 DEG.
948 LONGITUDE (MAD27)
ioWEST 109.798601 DEG.
NORTHING670851.36
STN --8 211 NJS610 ---
N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09
DATUMSPCS UTC (NAD 27)
STNiS 88'55'01" W STN 1326.92 STN 1334.24 STN 1320.17 SN
1331.78'1000 500 0 1000 2000
§URVEVOR'SSTATEMENT SCALE FEET
DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO, HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURtNG AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLY SHOWS THE LOCATIONOF ULT 12-5-4-2E AS STAKED ON THE G
LEGENDe WELL LOCATION 8262603O BOTTOM HOLE LOC. (APPROX) q.O CALCULATEDCORNERO FOUND MONUMENT UTAH PL 603--ÊÊÒ1A PREVIOUSLY FOUND MONUMENT
PIAT OF DRIEEEVG LOCATIONRIFFIN & ASSOCIATES, INC. FOR
panær6028 1414 ELNST, ROCKSPRINGS, WY82001 UTE ENERGYDRAWN:7/9/12- TCM SCALE: 1"= 1000' 2092 F/SL & 948'F NWSW, SECTION 5,
REVISED: NA DRG JOB No. 19386 T. 4 S., R. 2 E., U.S.MEXHIBIT f N
API Well Number: 43047540820000
R. 2 E. N
S 88'20 45" w N 88'16'32" E N 88°33 14" E N 86 13 56" ES¾a 1321.02° 5TN 1324.56' AC 1308.99' 1308.66' AC
.. LOT 2 LOT 1
LOT 4 LOT 3 m 12-5-4-2EGMEDEWAHOM
SCALE 1" = 1000'
STNAk - - - - -
·¯
¯-- SM.2' - -
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATED AT THE SWCORNER SECTION 5, T4S, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
N 88 23'23" E 5 s2eo.44LONGITUDE (NAD 83)
STNd ----- .,
---·--- ,--- STN WEST 109.799299 DEG
1320.11 1320.11 1320.11 1320.11·
LATITUDE (NAD 27)
. oNORTH 40.162755 DEG.
948 LONGITUDE (MAD27)
ioWEST 109.798601 DEG.
NORTHING670851.36
STN --8 211 NJS610 ---
N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09
DATUMSPCS UTC (NAD 27)
STNiS 88'55'01" W STN 1326.92 STN 1334.24 STN 1320.17 SN
1331.78'1000 500 0 1000 2000
§URVEVOR'SSTATEMENT SCALE FEET
DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO, HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURtNG AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLY SHOWS THE LOCATIONOF ULT 12-5-4-2E AS STAKED ON THE G
LEGENDe WELL LOCATION 8262603O BOTTOM HOLE LOC. (APPROX) q.O CALCULATEDCORNERO FOUND MONUMENT UTAH PL 603--ÊÊÒ1A PREVIOUSLY FOUND MONUMENT
PIAT OF DRIEEEVG LOCATIONRIFFIN & ASSOCIATES, INC. FOR
panær6028 1414 ELNST, ROCKSPRINGS, WY82001 UTE ENERGYDRAWN:7/9/12- TCM SCALE: 1"= 1000' 2092 F/SL & 948'F NWSW, SECTION 5,
REVISED: NA DRG JOB No. 19386 T. 4 S., R. 2 E., U.S.MEXHIBIT f N
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO A - 1 OF2 PROPOSED ROAD -•--·•-- EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO A - 1 OF2 PROPOSED ROAD -•--·•-- EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO A - 1 OF2 PROPOSED ROAD -•--·•-- EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO A - 1 OF2 PROPOSED ROAD -•--·•-- EXJSTING ROAD
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
T4S.
ULT12-5-4-2E
ILES -
15W
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPOA-20F2 PROPOSEDROAD-•--·•-- EXJSTINGROAD
RECEIVED: October 25,
API Well Number: 43047540820000
T4S.
ULT12-5-4-2E
ILES -
15W
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPOA-20F2 PROPOSEDROAD-•--·•-- EXJSTINGROAD
RECEIVED: October 25,
API Well Number: 43047540820000
T4S.
ULT12-5-4-2E
ILES -
15W
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPOA-20F2 PROPOSEDROAD-•--·•-- EXJSTINGROAD
RECEIVED: October 25,
API Well Number: 43047540820000
T4S.
ULT12-5-4-2E
ILES -
15W
PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPOA-20F2 PROPOSEDROAD-•--·•-- EXJSTINGROAD
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
ULTU1LIS-
DEEP RI 2E4-32-3-2E
l 3-2E
T
EgEP CRK TRIBALDE CRK GIB IC (JTE TRI AL-2EN 5- E 5-4 41-5 4-2E
-- I
DEEP CREEKA N OVERS y WERS , BOVE MSTMENTS TRIBAL
-6-4-at 46 4-2E eks-4 ETALTRHMLLAND§ ·¯
-
---- 6 ULT
12- -4-2E e 1- -
N10-6 ULT 12-5 4-2E -2E 0- I
UTE TRIBALUTE T AL-
. FRANI( D.#L3-4-4-2Ett4-4-44E
ULT ULT CWEATER13-6-4-2E 14- 4-2E
#15-6-4-2E 816- -2E 1 TRUSTEEETAL746.9'± TE
L4-9 4-2E
0-8-4-2E .CRK..RK TRIB LL 4-2E
-4 E 8 4 1-ß 4-2E
15 7 4 7 4C TR Br,L
4
RK TR[B 7 4 CRK T - 7 - 2E
. RANDLETT 95-17-4.-25 e --A-
APPROX. ROAD DISTURBANCE: 0.9± ACRES 1NST4LL CMP: Ci ,v ¡ , ,
. r'
PROPOSED ROAD FOR
RIFF/N & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2E
DRAWN: 7/10/12-DEH SCALE: 1"=2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 748.9'±
TOPO B PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
ULTU1LIS-
DEEP RI 2E4-32-3-2E
l 3-2E
T
EgEP CRK TRIBALDE CRK GIB IC (JTE TRI AL-2EN 5- E 5-4 41-5 4-2E
-- I
DEEP CREEKA N OVERS y WERS , BOVE MSTMENTS TRIBAL
-6-4-at 46 4-2E eks-4 ETALTRHMLLAND§ ·¯
-
---- 6 ULT
12- -4-2E e 1- -
N10-6 ULT 12-5 4-2E -2E 0- I
UTE TRIBALUTE T AL-
. FRANI( D.#L3-4-4-2Ett4-4-44E
ULT ULT CWEATER13-6-4-2E 14- 4-2E
#15-6-4-2E 816- -2E 1 TRUSTEEETAL746.9'± TE
L4-9 4-2E
0-8-4-2E .CRK..RK TRIB LL 4-2E
-4 E 8 4 1-ß 4-2E
15 7 4 7 4C TR Br,L
4
RK TR[B 7 4 CRK T - 7 - 2E
. RANDLETT 95-17-4.-25 e --A-
APPROX. ROAD DISTURBANCE: 0.9± ACRES 1NST4LL CMP: Ci ,v ¡ , ,
. r'
PROPOSED ROAD FOR
RIFF/N & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2E
DRAWN: 7/10/12-DEH SCALE: 1"=2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 748.9'±
TOPO B PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
ULTU1LIS-
DEEP RI 2E4-32-3-2E
l 3-2E
T
EgEP CRK TRIBALDE CRK GIB IC (JTE TRI AL-2EN 5- E 5-4 41-5 4-2E
-- I
DEEP CREEKA N OVERS y WERS , BOVE MSTMENTS TRIBAL
-6-4-at 46 4-2E eks-4 ETALTRHMLLAND§ ·¯
-
---- 6 ULT
12- -4-2E e 1- -
N10-6 ULT 12-5 4-2E -2E 0- I
UTE TRIBALUTE T AL-
. FRANI( D.#L3-4-4-2Ett4-4-44E
ULT ULT CWEATER13-6-4-2E 14- 4-2E
#15-6-4-2E 816- -2E 1 TRUSTEEETAL746.9'± TE
L4-9 4-2E
0-8-4-2E .CRK..RK TRIB LL 4-2E
-4 E 8 4 1-ß 4-2E
15 7 4 7 4C TR Br,L
4
RK TR[B 7 4 CRK T - 7 - 2E
. RANDLETT 95-17-4.-25 e --A-
APPROX. ROAD DISTURBANCE: 0.9± ACRES 1NST4LL CMP: Ci ,v ¡ , ,
. r'
PROPOSED ROAD FOR
RIFF/N & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2E
DRAWN: 7/10/12-DEH SCALE: 1"=2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 748.9'±
TOPO B PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
ULTU1LIS-
DEEP RI 2E4-32-3-2E
l 3-2E
T
EgEP CRK TRIBALDE CRK GIB IC (JTE TRI AL-2EN 5- E 5-4 41-5 4-2E
-- I
DEEP CREEKA N OVERS y WERS , BOVE MSTMENTS TRIBAL
-6-4-at 46 4-2E eks-4 ETALTRHMLLAND§ ·¯
-
---- 6 ULT
12- -4-2E e 1- -
N10-6 ULT 12-5 4-2E -2E 0- I
UTE TRIBALUTE T AL-
. FRANI( D.#L3-4-4-2Ett4-4-44E
ULT ULT CWEATER13-6-4-2E 14- 4-2E
#15-6-4-2E 816- -2E 1 TRUSTEEETAL746.9'± TE
L4-9 4-2E
0-8-4-2E .CRK..RK TRIB LL 4-2E
-4 E 8 4 1-ß 4-2E
15 7 4 7 4C TR Br,L
4
RK TR[B 7 4 CRK T - 7 - 2E
. RANDLETT 95-17-4.-25 e --A-
APPROX. ROAD DISTURBANCE: 0.9± ACRES 1NST4LL CMP: Ci ,v ¡ , ,
. r'
PROPOSED ROAD FOR
RIFF/N & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2E
DRAWN: 7/10/12-DEH SCALE: 1"=2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 748.9'±
TOPO B PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
ULT DEEP RK ;- -1E 4- E #2-
UT ' DE CRK uit REBAL-31 - 88 31 6¯ ¯3¯2E
32
DEEP CREEKA N INVESTMKVTS
ETAL
ULT 12-5-4 E
FRANK D
14- L EEEET
1L
UTE TREBAt#6-9-4-2E
COLEMnN FRIE
-ÙTEL3 COLÈMAN fRIBA2-19-4-2E
L½DKINGLE DEEP CRK TR2EBAL
ONE MILE RADIUS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(sonas2 so2e 1414 ELK ST., ROCK SPRINGS, WY82901 ULT 12-5-4-2EDRAI/VN:7/10/12-DEH SCALE: 1"=2000' SECTION Æ,T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO C PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
ULT DEEP RK ;- -1E 4- E #2-
UT ' DE CRK uit REBAL-31 - 88 31 6¯ ¯3¯2E
32
DEEP CREEKA N INVESTMKVTS
ETAL
ULT 12-5-4 E
FRANK D
14- L EEEET
1L
UTE TREBAt#6-9-4-2E
COLEMnN FRIE
-ÙTEL3 COLÈMAN fRIBA2-19-4-2E
L½DKINGLE DEEP CRK TR2EBAL
ONE MILE RADIUS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(sonas2 so2e 1414 ELK ST., ROCK SPRINGS, WY82901 ULT 12-5-4-2EDRAI/VN:7/10/12-DEH SCALE: 1"=2000' SECTION Æ,T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO C PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
ULT DEEP RK ;- -1E 4- E #2-
UT ' DE CRK uit REBAL-31 - 88 31 6¯ ¯3¯2E
32
DEEP CREEKA N INVESTMKVTS
ETAL
ULT 12-5-4 E
FRANK D
14- L EEEET
1L
UTE TREBAt#6-9-4-2E
COLEMnN FRIE
-ÙTEL3 COLÈMAN fRIBA2-19-4-2E
L½DKINGLE DEEP CRK TR2EBAL
ONE MILE RADIUS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(sonas2 so2e 1414 ELK ST., ROCK SPRINGS, WY82901 ULT 12-5-4-2EDRAI/VN:7/10/12-DEH SCALE: 1"=2000' SECTION Æ,T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO C PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
ULT DEEP RK ;- -1E 4- E #2-
UT ' DE CRK uit REBAL-31 - 88 31 6¯ ¯3¯2E
32
DEEP CREEKA N INVESTMKVTS
ETAL
ULT 12-5-4 E
FRANK D
14- L EEEET
1L
UTE TREBAt#6-9-4-2E
COLEMnN FRIE
-ÙTEL3 COLÈMAN fRIBA2-19-4-2E
L½DKINGLE DEEP CRK TR2EBAL
ONE MILE RADIUS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY
(sonas2 so2e 1414 ELK ST., ROCK SPRINGS, WY82901 ULT 12-5-4-2EDRAI/VN:7/10/12-DEH SCALE: 1"=2000' SECTION Æ,T4S, R2E
REVISED: NA DRG JOB No. 19386
TOPO C PROPOSED ROAD - - - - - - - EXJSTING ROAD
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
- -__ IE 1RIBAL- -ULT /
SU1LIDE P RK
4-32-3-2E- -1E 94- E
-
5-3U 3-2E ULT 7 3 - DE CR EBA
--
1 6 -2E
1 -
Eet. 3-
---- EgEP RK TRIBALDE CRK GIB IC - UTE TRIÈAL
T 4 S -2EN 5- E 5- - - 41-5 4-2E
-- _ - r END SERVEY ATDEEP CREEK '
A ES B E4 IN ThfENTS T in EI7EELIVE
yggg IBALBEGIN SURVE) I ---~ -4-4-2E
- LANDSULTULT so-¿_» - T UT TRIBAL
12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--
· - UTE TRIBALUTE T AL-
. FRANK D,#L3-4-4-2E#l4-4 <<E
CARPENTER UT TRIBAL13-6 4-2E 14-ULT4-2E
#15-6LT4-2E816- 2E
1 TRUSTEEETAL16- 4-2E
I4E
4
N
10-9-4-2E
-4
4 ELL 4-2E
DE 7 4 3 8 4 8 42EBr,L
COL TR
41742
EMANT Alg3-18-4-4 2E
-18-4-2
L 7 4 CRK T -CL7¯E
2E
AN TT 5-1 ._4-2Ç.
PROPOSED PIPELINE FOR
RIFFIN & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCN SPRINGS. WY82901 ULT 12-5-4-2E
DRAI/VN:7/10/12-DEH SCALE: 1"-2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 725.7'±
TOPO D PROPOSED P/PELINE - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
- -__ IE 1RIBAL- -ULT /
SU1LIDE P RK
4-32-3-2E- -1E 94- E
-
5-3U 3-2E ULT 7 3 - DE CR EBA
--
1 6 -2E
1 -
Eet. 3-
---- EgEP RK TRIBALDE CRK GIB IC - UTE TRIÈAL
T 4 S -2EN 5- E 5- - - 41-5 4-2E
-- _ - r END SERVEY ATDEEP CREEK '
A ES B E4 IN ThfENTS T in EI7EELIVE
yggg IBALBEGIN SURVE) I ---~ -4-4-2E
- LANDSULTULT so-¿_» - T UT TRIBAL
12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--
· - UTE TRIBALUTE T AL-
. FRANK D,#L3-4-4-2E#l4-4 <<E
CARPENTER UT TRIBAL
13-6 4-2E 14-ULT4-2E#15-6LT4-2E
816- 2E1 TRUSTEEETAL
16- 4-2E
I4E
4
N
10-9-4-2E
-4
4 ELL 4-2E
DE 7 4 3 8 4 8 42EBr,L
COL TR
41742
EMANT Alg3-18-4-4 2E
-18-4-2
L 7 4 CRK T -CL7¯E
2E
AN TT 5-1 ._4-2Ç.
PROPOSED PIPELINE FOR
RIFFIN & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCN SPRINGS. WY82901 ULT 12-5-4-2E
DRAI/VN:7/10/12-DEH SCALE: 1"-2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 725.7'±
TOPO D PROPOSED P/PELINE - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
- -__ IE 1RIBAL- -ULT /
SU1LIDE P RK
4-32-3-2E- -1E 94- E
-
5-3U 3-2E ULT 7 3 - DE CR EBA
--
1 6 -2E
1 -
Eet. 3-
---- EgEP RK TRIBALDE CRK GIB IC - UTE TRIÈAL
T 4 S -2EN 5- E 5- - - 41-5 4-2E
-- _ - r END SERVEY ATDEEP CREEK '
A ES B E4 IN ThfENTS T in EI7EELIVE
yggg IBALBEGIN SURVE) I ---~ -4-4-2E
- LANDSULTULT so-¿_» - T UT TRIBAL
12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--
· - UTE TRIBALUTE T AL-
. FRANK D,#L3-4-4-2E#l4-4 <<E
CARPENTER UT TRIBAL
13-6 4-2E 14-ULT4-2E#15-6LT4-2E
816- 2E1 TRUSTEEETAL
16- 4-2E
I4E
4
N
10-9-4-2E
-4
4 ELL 4-2E
DE 7 4 3 8 4 8 42EBr,L
COL TR
41742
EMANT Alg3-18-4-4 2E
-18-4-2
L 7 4 CRK T -CL7¯E
2E
AN TT 5-1 ._4-2Ç.
PROPOSED PIPELINE FOR
RIFFIN & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCN SPRINGS. WY82901 ULT 12-5-4-2E
DRAI/VN:7/10/12-DEH SCALE: 1"-2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 725.7'±
TOPO D PROPOSED P/PELINE - - - - - EXJSTING ROAD
RECEIVED: October 25,
API Well Number: 43047540820000
- -__ IE 1RIBAL- -ULT /
SU1LIDE P RK
4-32-3-2E- -1E 94- E
-
5-3U 3-2E ULT 7 3 - DE CR EBA
--
1 6 -2E
1 -
Eet. 3-
---- EgEP RK TRIBALDE CRK GIB IC - UTE TRIÈAL
T 4 S -2EN 5- E 5- - - 41-5 4-2E
-- _ - r END SERVEY ATDEEP CREEK '
A ES B E4 IN ThfENTS T in EI7EELIVE
yggg IBALBEGIN SURVE) I ---~ -4-4-2E
- LANDSULTULT so-¿_» - T UT TRIBAL
12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--
· - UTE TRIBALUTE T AL-
. FRANK D,#L3-4-4-2E#l4-4 <<E
CARPENTER UT TRIBAL
13-6 4-2E 14-ULT4-2E#15-6LT4-2E
816- 2E1 TRUSTEEETAL
16- 4-2E
I4E
4
N
10-9-4-2E
-4
4 ELL 4-2E
DE 7 4 3 8 4 8 42EBr,L
COL TR
41742
EMANT Alg3-18-4-4 2E
-18-4-2
L 7 4 CRK T -CL7¯E
2E
AN TT 5-1 ._4-2Ç.
PROPOSED PIPELINE FOR
RIFFIN & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCN SPRINGS. WY82901 ULT 12-5-4-2E
DRAI/VN:7/10/12-DEH SCALE: 1"-2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 725.7'±
TOPO D PROPOSED P/PELINE - - - - - EXJSTING ROAD
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 430475Ù820000
MEMORANDUM of SURFACE USE AGREEMENT AND GRANT OF EASEMENTS
Todd Kalstrom is the Vice President of Land for Ute Energy LLC and Ute Energy UpstreamHoldings LLC, authorized to do business in Utah (hereinafter referred to as "Ute Energy"). UteEnergy owns, operates and manages oil and gas interests In Uintah and Duchesne Counties, Utah.
WHEREAS, that certain Surface Use Agreement and Grant of Easements ("Agreement") datedeffective April 26th, 2011 has been entered into by and between Utah Land Trust, whose addressis c/o Gilbert Maggs, as Trustee, 230 Park Avenue, Satellite Beach, FL 32937 ("Owner") and UteEnergy Upstfeam Holdings LLC, whose address is 1875 Lawrence Street, Suite 200, Denver, CO80202 ("Operator").
WHEREAS, as of the date referenced above, this Agreement replaces in all respect the existingagreement covering a portion of the Property listed below and made and entered into betweenFlying J Oil and Gas Inc., a Utah corporation and Utah Land Trust, and found at Entry Number2008007507 of the Uintah County Recorder's Office in Uintah County, Utah.
WHEREAS, Owner owns the surface estate of the real property in Uintah County, Utah (the"Property"), legally described as:
Township 3 South, Range 1 East, USMSection 25: S/2SWl4Section 26: S/2, S/2N/2Section 34: AIISection 35: N/2Section 36: All
Township 3 South, Range 2 East, USMSection 29: W/2Section 31: Wl2
Township 4 South, Range 2 East, USMSection 5: SW/4Section 6: S/2
WHEREAS, for an agreed upon monetary consideration, Operator may construct the necessarywell site pads for drilling, completion, re-completion, reworking, re-entry, production,maintenance and operation of wells ("Well Pads") on the Property. Ute Energy, its agents,employees, assigns, contractors and subcontractors, may enter upon and use the Well Pads for thepurposes of drilling, completing, producing, maintaining, and operating Wells to produce oil, gasand associated hydrocarbons produced from the Property, including the construction and use offrac pits, tank batteries, water disposal pits, production equipment, compressor sites and otherfacilities used to produce and market the oil, gas and associated hydrocarbons.
WHEREAS, Operator has the right to a non-exclusive access easement ("Road Easement") on theProperty for ingress and egress by Operator and its employees, contractors, sub-contractors,agents, and business invitees as needed to conduct oil and gas operations.
WHEREAS, Operator, its employees, contractors, sub-contractors, agents and business inviteeshas the right to a non-exclusive pipeline easement to construct, maintain, inspect, operate andrepair a pipeline or pipelines, pigging facilities and related appurtenances for the transportation ofoil, gas, petroleum products, water and any other substances recovered during oil and gasproduction.
WHEREAS, this Agreement shall run with the land and be binding upon and inure to the benefitof the parties and their respective heirs, successors and assigns as stated in this Agreement.
THERFORE, Operator is granted access to the surface estate and the Agree ent constitutes avalid and binding surface use agreement as required under Utah Admin. Co Rule R649-3-34(7).
This Memorandum is executed this 28 day of April,
To KalstromVi e President of
API Well Number: 430475Ù820000
MEMORANDUM of SURFACE USE AGREEMENT AND GRANT OF EASEMENTS
Todd Kalstrom is the Vice President of Land for Ute Energy LLC and Ute Energy UpstreamHoldings LLC, authorized to do business in Utah (hereinafter referred to as "Ute Energy"). UteEnergy owns, operates and manages oil and gas interests In Uintah and Duchesne Counties, Utah.
WHEREAS, that certain Surface Use Agreement and Grant of Easements ("Agreement") datedeffective April 26th, 2011 has been entered into by and between Utah Land Trust, whose addressis c/o Gilbert Maggs, as Trustee, 230 Park Avenue, Satellite Beach, FL 32937 ("Owner") and UteEnergy Upstfeam Holdings LLC, whose address is 1875 Lawrence Street, Suite 200, Denver, CO80202 ("Operator").
WHEREAS, as of the date referenced above, this Agreement replaces in all respect the existingagreement covering a portion of the Property listed below and made and entered into betweenFlying J Oil and Gas Inc., a Utah corporation and Utah Land Trust, and found at Entry Number2008007507 of the Uintah County Recorder's Office in Uintah County, Utah.
WHEREAS, Owner owns the surface estate of the real property in Uintah County, Utah (the"Property"), legally described as:
Township 3 South, Range 1 East, USMSection 25: S/2SWl4Section 26: S/2, S/2N/2Section 34: AIISection 35: N/2Section 36: All
Township 3 South, Range 2 East, USMSection 29: W/2Section 31: Wl2
Township 4 South, Range 2 East, USMSection 5: SW/4Section 6: S/2
WHEREAS, for an agreed upon monetary consideration, Operator may construct the necessarywell site pads for drilling, completion, re-completion, reworking, re-entry, production,maintenance and operation of wells ("Well Pads") on the Property. Ute Energy, its agents,employees, assigns, contractors and subcontractors, may enter upon and use the Well Pads for thepurposes of drilling, completing, producing, maintaining, and operating Wells to produce oil, gasand associated hydrocarbons produced from the Property, including the construction and use offrac pits, tank batteries, water disposal pits, production equipment, compressor sites and otherfacilities used to produce and market the oil, gas and associated hydrocarbons.
WHEREAS, Operator has the right to a non-exclusive access easement ("Road Easement") on theProperty for ingress and egress by Operator and its employees, contractors, sub-contractors,agents, and business invitees as needed to conduct oil and gas operations.
WHEREAS, Operator, its employees, contractors, sub-contractors, agents and business inviteeshas the right to a non-exclusive pipeline easement to construct, maintain, inspect, operate andrepair a pipeline or pipelines, pigging facilities and related appurtenances for the transportation ofoil, gas, petroleum products, water and any other substances recovered during oil and gasproduction.
WHEREAS, this Agreement shall run with the land and be binding upon and inure to the benefitof the parties and their respective heirs, successors and assigns as stated in this Agreement.
THERFORE, Operator is granted access to the surface estate and the Agree ent constitutes avalid and binding surface use agreement as required under Utah Admin. Co Rule R649-3-34(7).
This Memorandum is executed this 28 day of April,
To KalstromVi e President of
API Well Number: 430475Ù820000
MEMORANDUM of SURFACE USE AGREEMENT AND GRANT OF EASEMENTS
Todd Kalstrom is the Vice President of Land for Ute Energy LLC and Ute Energy UpstreamHoldings LLC, authorized to do business in Utah (hereinafter referred to as "Ute Energy"). UteEnergy owns, operates and manages oil and gas interests In Uintah and Duchesne Counties, Utah.
WHEREAS, that certain Surface Use Agreement and Grant of Easements ("Agreement") datedeffective April 26th, 2011 has been entered into by and between Utah Land Trust, whose addressis c/o Gilbert Maggs, as Trustee, 230 Park Avenue, Satellite Beach, FL 32937 ("Owner") and UteEnergy Upstfeam Holdings LLC, whose address is 1875 Lawrence Street, Suite 200, Denver, CO80202 ("Operator").
WHEREAS, as of the date referenced above, this Agreement replaces in all respect the existingagreement covering a portion of the Property listed below and made and entered into betweenFlying J Oil and Gas Inc., a Utah corporation and Utah Land Trust, and found at Entry Number2008007507 of the Uintah County Recorder's Office in Uintah County, Utah.
WHEREAS, Owner owns the surface estate of the real property in Uintah County, Utah (the"Property"), legally described as:
Township 3 South, Range 1 East, USMSection 25: S/2SWl4Section 26: S/2, S/2N/2Section 34: AIISection 35: N/2Section 36: All
Township 3 South, Range 2 East, USMSection 29: W/2Section 31: Wl2
Township 4 South, Range 2 East, USMSection 5: SW/4Section 6: S/2
WHEREAS, for an agreed upon monetary consideration, Operator may construct the necessarywell site pads for drilling, completion, re-completion, reworking, re-entry, production,maintenance and operation of wells ("Well Pads") on the Property. Ute Energy, its agents,employees, assigns, contractors and subcontractors, may enter upon and use the Well Pads for thepurposes of drilling, completing, producing, maintaining, and operating Wells to produce oil, gasand associated hydrocarbons produced from the Property, including the construction and use offrac pits, tank batteries, water disposal pits, production equipment, compressor sites and otherfacilities used to produce and market the oil, gas and associated hydrocarbons.
WHEREAS, Operator has the right to a non-exclusive access easement ("Road Easement") on theProperty for ingress and egress by Operator and its employees, contractors, sub-contractors,agents, and business invitees as needed to conduct oil and gas operations.
WHEREAS, Operator, its employees, contractors, sub-contractors, agents and business inviteeshas the right to a non-exclusive pipeline easement to construct, maintain, inspect, operate andrepair a pipeline or pipelines, pigging facilities and related appurtenances for the transportation ofoil, gas, petroleum products, water and any other substances recovered during oil and gasproduction.
WHEREAS, this Agreement shall run with the land and be binding upon and inure to the benefitof the parties and their respective heirs, successors and assigns as stated in this Agreement.
THERFORE, Operator is granted access to the surface estate and the Agree ent constitutes avalid and binding surface use agreement as required under Utah Admin. Co Rule R649-3-34(7).
This Memorandum is executed this 28 day of April,
To KalstromVi e President of
API Well Number: 430475Ù820000
MEMORANDUM of SURFACE USE AGREEMENT AND GRANT OF EASEMENTS
Todd Kalstrom is the Vice President of Land for Ute Energy LLC and Ute Energy UpstreamHoldings LLC, authorized to do business in Utah (hereinafter referred to as "Ute Energy"). UteEnergy owns, operates and manages oil and gas interests In Uintah and Duchesne Counties, Utah.
WHEREAS, that certain Surface Use Agreement and Grant of Easements ("Agreement") datedeffective April 26th, 2011 has been entered into by and between Utah Land Trust, whose addressis c/o Gilbert Maggs, as Trustee, 230 Park Avenue, Satellite Beach, FL 32937 ("Owner") and UteEnergy Upstfeam Holdings LLC, whose address is 1875 Lawrence Street, Suite 200, Denver, CO80202 ("Operator").
WHEREAS, as of the date referenced above, this Agreement replaces in all respect the existingagreement covering a portion of the Property listed below and made and entered into betweenFlying J Oil and Gas Inc., a Utah corporation and Utah Land Trust, and found at Entry Number2008007507 of the Uintah County Recorder's Office in Uintah County, Utah.
WHEREAS, Owner owns the surface estate of the real property in Uintah County, Utah (the"Property"), legally described as:
Township 3 South, Range 1 East, USMSection 25: S/2SWl4Section 26: S/2, S/2N/2Section 34: AIISection 35: N/2Section 36: All
Township 3 South, Range 2 East, USMSection 29: W/2Section 31: Wl2
Township 4 South, Range 2 East, USMSection 5: SW/4Section 6: S/2
WHEREAS, for an agreed upon monetary consideration, Operator may construct the necessarywell site pads for drilling, completion, re-completion, reworking, re-entry, production,maintenance and operation of wells ("Well Pads") on the Property. Ute Energy, its agents,employees, assigns, contractors and subcontractors, may enter upon and use the Well Pads for thepurposes of drilling, completing, producing, maintaining, and operating Wells to produce oil, gasand associated hydrocarbons produced from the Property, including the construction and use offrac pits, tank batteries, water disposal pits, production equipment, compressor sites and otherfacilities used to produce and market the oil, gas and associated hydrocarbons.
WHEREAS, Operator has the right to a non-exclusive access easement ("Road Easement") on theProperty for ingress and egress by Operator and its employees, contractors, sub-contractors,agents, and business invitees as needed to conduct oil and gas operations.
WHEREAS, Operator, its employees, contractors, sub-contractors, agents and business inviteeshas the right to a non-exclusive pipeline easement to construct, maintain, inspect, operate andrepair a pipeline or pipelines, pigging facilities and related appurtenances for the transportation ofoil, gas, petroleum products, water and any other substances recovered during oil and gasproduction.
WHEREAS, this Agreement shall run with the land and be binding upon and inure to the benefitof the parties and their respective heirs, successors and assigns as stated in this Agreement.
THERFORE, Operator is granted access to the surface estate and the Agree ent constitutes avalid and binding surface use agreement as required under Utah Admin. Co Rule R649-3-34(7).
This Memorandum is executed this 28 day of April,
To KalstromVi e President of
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Entry 2011003143Book 1231 Page 5?6
ACKNOWLEDGEMENT
STATE OF COLORADO)) ss
COUNTY OF DENVER )
The foregoing instrument was acknowledged before me by Todd Kalstrom, Vice President of Land for UteEnergy LLC and Ute Energy Upstream Holdings LLC thi 8th day of il, 201l.
Notary PublicNotary Seal:
y Commission expires: KARIQUARLESNOTARYPUBLIC,STATEOFCOLORADO
Dat MyComm. Expires September 15, 2014i
I
Book 1231 Page 575-sk son0029- PR-11 0 :56RANDYSIMMONGRECORDER:UINTAHCOUNTY,UTAHUTEENERGYLLCATTNFELICIAGATES-MPD BOX789 FT DUCHEGNE,UT84026Rec By: SYLENEACCUTTORODP,
API Well Number: 43047540820000
Entry 2011003143Book 1231 Page 5?6
ACKNOWLEDGEMENT
STATE OF COLORADO)) ss
COUNTY OF DENVER )
The foregoing instrument was acknowledged before me by Todd Kalstrom, Vice President of Land for UteEnergy LLC and Ute Energy Upstream Holdings LLC thi 8th day of il, 201l.
Notary PublicNotary Seal:
y Commission expires: KARIQUARLESNOTARYPUBLIC,STATEOFCOLORADO
Dat MyComm. Expires September 15, 2014i
I
Book 1231 Page 575-sk son0029- PR-11 0 :56
RANDYSIMMONGRECORDER:UINTAHCOUNTY,UTAHUTEENERGYLLCATTNFELICIAGATES-MPD BOX789 FT DUCHEGNE,UT84026Rec By: SYLENEACCUTTORODP,
API Well Number: 43047540820000
Entry 2011003143Book 1231 Page 5?6
ACKNOWLEDGEMENT
STATE OF COLORADO)) ss
COUNTY OF DENVER )
The foregoing instrument was acknowledged before me by Todd Kalstrom, Vice President of Land for UteEnergy LLC and Ute Energy Upstream Holdings LLC thi 8th day of il, 201l.
Notary PublicNotary Seal:
y Commission expires: KARIQUARLESNOTARYPUBLIC,STATEOFCOLORADO
Dat MyComm. Expires September 15, 2014i
I
Book 1231 Page 575-sk son0029- PR-11 0 :56
RANDYSIMMONGRECORDER:UINTAHCOUNTY,UTAHUTEENERGYLLCATTNFELICIAGATES-MPD BOX789 FT DUCHEGNE,UT84026Rec By: SYLENEACCUTTORODP,
API Well Number: 43047540820000
Entry 2011003143Book 1231 Page 5?6
ACKNOWLEDGEMENT
STATE OF COLORADO)) ss
COUNTY OF DENVER )
The foregoing instrument was acknowledged before me by Todd Kalstrom, Vice President of Land for UteEnergy LLC and Ute Energy Upstream Holdings LLC thi 8th day of il, 201l.
Notary PublicNotary Seal:
y Commission expires: KARIQUARLESNOTARYPUBLIC,STATEOFCOLORADO
Dat MyComm. Expires September 15, 2014i
I
Book 1231 Page 575-sk son0029- PR-11 0 :56
RANDYSIMMONGRECORDER:UINTAHCOUNTY,UTAHUTEENERGYLLCATTNFELICIAGATES-MPD BOX789 FT DUCHEGNE,UT84026Rec By: SYLENEACCUTTORODP,
RECEIVED: October 25, 2013
9.5" TIME SAVER WELLHEAD SYSTEMWITH DRILL SPOOL,
AND BOP CONFIGURATION
Top of Casing Head
Bottom of Casing Head
11" 3MTop of BOP Adapter
11" 3M
519 E . 300 S.
Vernal, U T 84078
P435-781-0434
F435-789-5656
11" 3M
11" 3M
Rotating Head
3" 3K Outlet
Pipe Rams
Blind Rams
Double 11" 3K BOP
BOP Adapter QuickConnect
9.5" Time SaverCasing Head
Inlet to Manifold
3K Choke 3K Choke
3-1/8" 3K Gate Valves
3-1/8" 3K Gate Valves
Choke Manifold
Oct, 18, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
CAMERON Oct, 18, 2013519 E. 300 S.Vernal, UT 84078P435-781-0434F435-789-5656
Choke Manifold
Crescent Point
9.5" T1MESAVERWELLHEADSYSTEMWITHDRILLSPOOL,
AND BOP CONFIGURAT10N 3-1/8" 3K Gate Valves
3-1/8" 3K Gate Valves
Rotating Head
11" 3M 3K Choke 3K Choke
ANNULAR Inlet to Manifold
11"3M
Pipe Rams
L Double 11"3K BOP
Blind Rams
11" 3M 3" 3KOutlet
DRILLINGSPOOL
TopofBOPAdapter 11"3M
9.5" Time Saver. Casing Head
BOP Adapter QuickConnect
2" BALL VALVE
Bottomof Casing Head
9-5/8" CASING
RECEIVED: October 25,
API Well Number: 43047540820000
CAMERON Oct, 18, 2013519 E. 300 S.Vernal, UT 84078P435-781-0434F435-789-5656
Choke Manifold
Crescent Point
9.5" T1MESAVERWELLHEADSYSTEMWITHDRILLSPOOL,
AND BOP CONFIGURAT10N 3-1/8" 3K Gate Valves
3-1/8" 3K Gate Valves
Rotating Head
11" 3M 3K Choke 3K Choke
ANNULAR Inlet to Manifold
11"3M
Pipe Rams
L Double 11"3K BOP
Blind Rams
11" 3M 3" 3KOutlet
DRILLINGSPOOL
TopofBOPAdapter 11"3M
9.5" Time Saver. Casing Head
BOP Adapter QuickConnect
2" BALL VALVE
Bottomof Casing Head
9-5/8" CASING
RECEIVED: October 25,
API Well Number: 43047540820000
CAMERON Oct, 18, 2013519 E. 300 S.Vernal, UT 84078P435-781-0434F435-789-5656
Choke Manifold
Crescent Point
9.5" T1MESAVERWELLHEADSYSTEMWITHDRILLSPOOL,
AND BOP CONFIGURAT10N 3-1/8" 3K Gate Valves
3-1/8" 3K Gate Valves
Rotating Head
11" 3M 3K Choke 3K Choke
ANNULAR Inlet to Manifold
11"3M
Pipe Rams
L Double 11"3K BOP
Blind Rams
11" 3M 3" 3KOutlet
DRILLINGSPOOL
TopofBOPAdapter 11"3M
9.5" Time Saver. Casing Head
BOP Adapter QuickConnect
2" BALL VALVE
Bottomof Casing Head
9-5/8" CASING
RECEIVED: October 25,
API Well Number: 43047540820000
CAMERON Oct, 18, 2013519 E. 300 S.Vernal, UT 84078P435-781-0434F435-789-5656
Choke Manifold
Crescent Point
9.5" T1MESAVERWELLHEADSYSTEMWITHDRILLSPOOL,
AND BOP CONFIGURAT10N 3-1/8" 3K Gate Valves
3-1/8" 3K Gate Valves
Rotating Head
11" 3M 3K Choke 3K Choke
ANNULAR Inlet to Manifold
11"3M
Pipe Rams
L Double 11"3K BOP
Blind Rams
11" 3M 3" 3KOutlet
DRILLINGSPOOL
TopofBOPAdapter 11"3M
9.5" Time Saver. Casing Head
BOP Adapter QuickConnect
2" BALL VALVE
Bottomof Casing Head
9-5/8" CASING
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000I
Crescent Point assivisstreet.suiteisooENERGY U.S . CCRP Denver,CO80202
September 4, 2013
5tate of Utah, Division of Oil, Gas and MiningAttention: Diana Mason1594 West North TempleSalt Lake City, UT 84116
RE: Exception Location RequestULT 12-5-4-2ETownship 4 South, Range 2 East, USMSection 5: NW/4SW/4Uintah County, Utah
Dear Ms. Mason:
Crescent Point Energy U.S. Corp (Crescent Point) proposes to drill the captioned well with a surface location of 2,091'FSL; 948' FWL of Section 5, Township 4 South, Range 2 East, USM, Uintah County, Utah. A copy of the survey plat isattached hereto for your reference. Crescent Point is the only owner of oil and gas leases within a 460' radius of theintended wellbore.
Due to these circumstances, Crescent Point respectfully requests that DOGM administratively grant an exceptionlocation for the ULT12-5-4-2E.
Landman
www.crescentpointenergy.com
API Well Number: 43047540820000I
Crescent Point assivisstreet.suiteisooENERGY U.S . CCRP Denver,CO80202
September 4, 2013
5tate of Utah, Division of Oil, Gas and MiningAttention: Diana Mason1594 West North TempleSalt Lake City, UT 84116
RE: Exception Location RequestULT 12-5-4-2ETownship 4 South, Range 2 East, USMSection 5: NW/4SW/4Uintah County, Utah
Dear Ms. Mason:
Crescent Point Energy U.S. Corp (Crescent Point) proposes to drill the captioned well with a surface location of 2,091'FSL; 948' FWL of Section 5, Township 4 South, Range 2 East, USM, Uintah County, Utah. A copy of the survey plat isattached hereto for your reference. Crescent Point is the only owner of oil and gas leases within a 460' radius of theintended wellbore.
Due to these circumstances, Crescent Point respectfully requests that DOGM administratively grant an exceptionlocation for the ULT12-5-4-2E.
Landman
www.crescentpointenergy.com
API Well Number: 43047540820000I
Crescent Point assivisstreet.suiteisooENERGY U.S . CCRP Denver,CO80202
September 4, 2013
5tate of Utah, Division of Oil, Gas and MiningAttention: Diana Mason1594 West North TempleSalt Lake City, UT 84116
RE: Exception Location RequestULT 12-5-4-2ETownship 4 South, Range 2 East, USMSection 5: NW/4SW/4Uintah County, Utah
Dear Ms. Mason:
Crescent Point Energy U.S. Corp (Crescent Point) proposes to drill the captioned well with a surface location of 2,091'FSL; 948' FWL of Section 5, Township 4 South, Range 2 East, USM, Uintah County, Utah. A copy of the survey plat isattached hereto for your reference. Crescent Point is the only owner of oil and gas leases within a 460' radius of theintended wellbore.
Due to these circumstances, Crescent Point respectfully requests that DOGM administratively grant an exceptionlocation for the ULT12-5-4-2E.
Landman
www.crescentpointenergy.com
API Well Number: 43047540820000I
Crescent Point assivisstreet.suiteisooENERGY U.S . CCRP Denver,CO80202
September 4, 2013
5tate of Utah, Division of Oil, Gas and MiningAttention: Diana Mason1594 West North TempleSalt Lake City, UT 84116
RE: Exception Location RequestULT 12-5-4-2ETownship 4 South, Range 2 East, USMSection 5: NW/4SW/4Uintah County, Utah
Dear Ms. Mason:
Crescent Point Energy U.S. Corp (Crescent Point) proposes to drill the captioned well with a surface location of 2,091'FSL; 948' FWL of Section 5, Township 4 South, Range 2 East, USM, Uintah County, Utah. A copy of the survey plat isattached hereto for your reference. Crescent Point is the only owner of oil and gas leases within a 460' radius of theintended wellbore.
Due to these circumstances, Crescent Point respectfully requests that DOGM administratively grant an exceptionlocation for the ULT12-5-4-2E.
Landman
www.crescentpointenergy.com
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
R. 2 E. N
S 88¯20'45" w N 88'15'32" E N 88 33 14" E N 88'13'56" ESTN' 1321.02' STN 1324.56" AC 1308.99' 1308.66' AC
LOT 2 LOT 1
09 LOT 4 LOT 3 o.12-5-4-2E 4
UNGNEDÉWAHOM scALE 1" = 1000'
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATEDAT THE SWCORNER SECTION 5, T45, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
5 ,
LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /
STN - ---- -- -'- .-----
--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil
LATITUDE (NAD27)NORTH 40.162755 DEG.LONGITUDE (NAD 27)WEST 109.798601 DEG.
NORTHING6¯/0851.36
s1N 3--?U211"_.....
-89
N 88'42'32 E 265137'- EASTWG
1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09
z z z
- o o - E - 9 DATUMSPCS UTC (NAD 27)
STN 5 88'55'01" W STN 1328.92 STN 1334.2 STN 132017 S(N
1331.781000 500 0 1000 20DO
STIRVEYOR'SSTATEMENT SCALE FEET
I, DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO.HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURING AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLYSHOWS THE LOCATJON OF ULT 12-5-4-2E AS STAKED ON THE GROUND
LEGEND< > WELLLOCATION 82626 3
BOTTOM HOLE LOC. (APPROX)
O CALCULATED CORNERO FOUND MONUMENT UTAH 03-2201& PREVIOUSLY FOUND MONUMENT
PLAT OF DRELEVG LOCATIONRIFFIN & ASSOC/ATES, ING. FOR
(907)362-502B 1414 ELKST., ROCK SPRINGS, WY82901 f/TE ENERGYDRAWN: 7/9/12 - TCM SCALE: i"= 1000' 2091' F/SL & 948' F/WL, NWSW, SECTION 5,
REVISED: NA ORG JOB No. 19386 T. 4 S., R. 2 E., U.S.ME¥HIB/T 1 *
API Well Number: 43047540820000
R. 2 E. N
S 88¯20'45" w N 88'15'32" E N 88 33 14" E N 88'13'56" ESTN' 1321.02' STN 1324.56" AC 1308.99' 1308.66' AC
LOT 2 LOT 1
09 LOT 4 LOT 3 o.12-5-4-2E 4
UNGNEDÉWAHOM scALE 1" = 1000'
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATEDAT THE SWCORNER SECTION 5, T45, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
5 ,
LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /
STN - ---- -- -'- .-----
--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil
LATITUDE (NAD27)NORTH 40.162755 DEG.LONGITUDE (NAD 27)WEST 109.798601 DEG.
NORTHING6¯/0851.36
s1N 3--?U211"_.....
-89
N 88'42'32 E 265137'- EASTWG
1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09
z z z
- o o - E - 9 DATUMSPCS UTC (NAD 27)
STN 5 88'55'01" W STN 1328.92 STN 1334.2 STN 132017 S(N
1331.781000 500 0 1000 20DO
STIRVEYOR'SSTATEMENT SCALE FEET
I, DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO.HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURING AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLYSHOWS THE LOCATJON OF ULT 12-5-4-2E AS STAKED ON THE GROUND
LEGEND< > WELLLOCATION 82626 3
BOTTOM HOLE LOC. (APPROX)
O CALCULATED CORNERO FOUND MONUMENT UTAH 03-2201& PREVIOUSLY FOUND MONUMENT
PLAT OF DRELEVG LOCATIONRIFFIN & ASSOC/ATES, ING. FOR
(907)362-502B 1414 ELKST., ROCK SPRINGS, WY82901 f/TE ENERGYDRAWN: 7/9/12 - TCM SCALE: i"= 1000' 2091' F/SL & 948' F/WL, NWSW, SECTION 5,
REVISED: NA ORG JOB No. 19386 T. 4 S., R. 2 E., U.S.ME¥HIB/T 1 *
API Well Number: 43047540820000
R. 2 E. N
S 88¯20'45" w N 88'15'32" E N 88 33 14" E N 88'13'56" ESTN' 1321.02' STN 1324.56" AC 1308.99' 1308.66' AC
LOT 2 LOT 1
09 LOT 4 LOT 3 o.12-5-4-2E 4
UNGNEDÉWAHOM scALE 1" = 1000'
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATEDAT THE SWCORNER SECTION 5, T45, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
5 ,
LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /
STN - ---- -- -'- .-----
--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil
LATITUDE (NAD27)NORTH 40.162755 DEG.LONGITUDE (NAD 27)WEST 109.798601 DEG.
NORTHING6¯/0851.36
s1N 3--?U211"_.....
-89
N 88'42'32 E 265137'- EASTWG
1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09
z z z
- o o - E - 9 DATUMSPCS UTC (NAD 27)
STN 5 88'55'01" W STN 1328.92 STN 1334.2 STN 132017 S(N
1331.781000 500 0 1000 20DO
STIRVEYOR'SSTATEMENT SCALE FEET
I, DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO.HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURING AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLYSHOWS THE LOCATJON OF ULT 12-5-4-2E AS STAKED ON THE GROUND
LEGEND< > WELLLOCATION 82626 3
BOTTOM HOLE LOC. (APPROX)
O CALCULATED CORNERO FOUND MONUMENT UTAH 03-2201& PREVIOUSLY FOUND MONUMENT
PLAT OF DRELEVG LOCATIONRIFFIN & ASSOC/ATES, ING. FOR
(907)362-502B 1414 ELKST., ROCK SPRINGS, WY82901 f/TE ENERGYDRAWN: 7/9/12 - TCM SCALE: i"= 1000' 2091' F/SL & 948' F/WL, NWSW, SECTION 5,
REVISED: NA ORG JOB No. 19386 T. 4 S., R. 2 E., U.S.ME¥HIB/T 1 *
API Well Number: 43047540820000
R. 2 E. N
S 88¯20'45" w N 88'15'32" E N 88 33 14" E N 88'13'56" ESTN' 1321.02' STN 1324.56" AC 1308.99' 1308.66' AC
LOT 2 LOT 1
09 LOT 4 LOT 3 o.12-5-4-2E 4
UNGNEDÉWAHOM scALE 1" = 1000'
z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATEDAT THE SWCORNER SECTION 5, T45, R2E,ELEVATION: 5117'
LATITUDE (NAD 83)NORTH 40.162717 DEG.
5 ,
LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /
STN - ---- -- -'- .-----
--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil
LATITUDE (NAD27)NORTH 40.162755 DEG.LONGITUDE (NAD 27)WEST 109.798601 DEG.
NORTHING6¯/0851.36
s1N 3--?U211"_.....
-89
N 88'42'32 E 265137'- EASTWG
1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09
z z z
- o o - E - 9 DATUMSPCS UTC (NAD 27)
STN 5 88'55'01" W STN 1328.92 STN 1334.2 STN 132017 S(N
1331.781000 500 0 1000 20DO
STIRVEYOR'SSTATEMENT SCALE FEET
I, DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO.HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURING AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLYSHOWS THE LOCATJON OF ULT 12-5-4-2E AS STAKED ON THE GROUND
LEGEND< > WELLLOCATION 82626 3
BOTTOM HOLE LOC. (APPROX)
O CALCULATED CORNERO FOUND MONUMENT UTAH 03-2201& PREVIOUSLY FOUND MONUMENT
PLAT OF DRELEVG LOCATIONRIFFIN & ASSOC/ATES, ING. FOR
(907)362-502B 1414 ELKST., ROCK SPRINGS, WY82901 f/TE ENERGYDRAWN: 7/9/12 - TCM SCALE: i"= 1000' 2091' F/SL & 948' F/WL, NWSW, SECTION 5,
REVISED: NA ORG JOB No. 19386 T. 4 S., R. 2 E., U.S.ME¥HIB/T 1 *
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
o APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'FINISHED ELEVATION: 5063.7'
/ 158' STA 4+00162'
I I / \\
' COMPLET/ONSP/T/ 140' x 100' x 12'
24, J8J Bb/s/ 19,478 Bb/s STA 3+00| | WITH 2' FREEBOARD \
/ 1.5 C 6.
/ --RESERVE P/T,/ 100' X 60' X 12'/
\ / 9,JJ6 Bb/s /| 15 FLARE PIT7,224 Bb/s/ I \
/38
2' FREEBOCARD \STA 2+2000 / 5
162' 148 STA 0+00S 14 56'57" E ..' . 310
EXCE3S M TER AL P
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEET
UTE ENERGYIFFIN & ASSOCIATES, INC. ULT12-5-4-2E
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM SCALE: 1"= 80'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
o APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'FINISHED ELEVATION: 5063.7'
/ 158' STA 4+00162'
I I / \\
' COMPLET/ONSP/T/ 140' x 100' x 12'
24, J8J Bb/s/ 19,478 Bb/s STA 3+00| | WITH 2' FREEBOARD \
/ 1.5 C 6.
/ --RESERVE P/T,/ 100' X 60' X 12'/
\ / 9,JJ6 Bb/s /| 15 FLARE PIT7,224 Bb/s/ I \
/38
2' FREEBOCARD \STA 2+2000 / 5
162' 148 STA 0+00S 14 56'57" E ..' . 310
EXCE3S M TER AL P
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEET
UTE ENERGYIFFIN & ASSOCIATES, INC. ULT12-5-4-2E
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM SCALE: 1"= 80'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
o APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'FINISHED ELEVATION: 5063.7'
/ 158' STA 4+00162'
I I / \\
' COMPLET/ONSP/T/ 140' x 100' x 12'
24, J8J Bb/s/ 19,478 Bb/s STA 3+00| | WITH 2' FREEBOARD \
/ 1.5 C 6.
/ --RESERVE P/T,/ 100' X 60' X 12'/
\ / 9,JJ6 Bb/s /| 15 FLARE PIT7,224 Bb/s/ I \
/38
2' FREEBOCARD \STA 2+2000 / 5
162' 148 STA 0+00S 14 56'57" E ..' . 310
EXCE3S M TER AL P
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEET
UTE ENERGYIFFIN & ASSOCIATES, INC. ULT12-5-4-2E
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM SCALE: 1"= 80'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
o APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'FINISHED ELEVATION: 5063.7'
/ 158' STA 4+00162'
I I / \\
' COMPLET/ONSP/T/ 140' x 100' x 12'
24, J8J Bb/s/ 19,478 Bb/s STA 3+00| | WITH 2' FREEBOARD \
/ 1.5 C 6.
/ --RESERVE P/T,/ 100' X 60' X 12'/
\ / 9,JJ6 Bb/s /| 15 FLARE PIT7,224 Bb/s/ I \
/38
2' FREEBOCARD \STA 2+2000 / 5
162' 148 STA 0+00S 14 56'57" E ..' . 310
EXCE3S M TER AL P
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEET
UTE ENERGYIFFIN & ASSOCIATES, INC. ULT12-5-4-2E
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM SCALE: 1"= 80'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
120'162' 38'
100' FI BIII
I ¯
l 100'I
I
^o
'¯ lIII
162' 148'
PAD LAYOUTUTE ENERGYIFFIN & ASSOCIATES, INC.
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 ULT 12-5-4-2EDRAWN: 7/9/12- TCM SCALE: 1"= 80' SECTION 5, T4S, R2E
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1A FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
120'162' 38'
100' FI BIII
I ¯
l 100'I
I
^o
'¯ lIII
162' 148'
PAD LAYOUTUTE ENERGYIFFIN & ASSOCIATES, INC.
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 ULT 12-5-4-2EDRAWN: 7/9/12- TCM SCALE: 1"= 80' SECTION 5, T4S, R2E
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1A FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
120'162' 38'
100' FI BIII
I ¯
l 100'I
I
^o
'¯ lIII
162' 148'
PAD LAYOUTUTE ENERGYIFFIN & ASSOCIATES, INC.
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 ULT 12-5-4-2EDRAWN: 7/9/12- TCM SCALE: 1"= 80' SECTION 5, T4S, R2E
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1A FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
120'162' 38'
100' FI BIII
I ¯
l 100'I
I
^o
'¯ lIII
162' 148'
PAD LAYOUTUTE ENERGYIFFIN & ASSOCIATES, INC.
(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 ULT 12-5-4-2EDRAWN: 7/9/12- TCM SCALE: 1"= 80' SECTION 5, T4S, R2E
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1A FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
GRADE
5060 FILL.---- - I
' CUT5060
I I I II I I I5050 5050
-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 4+00
5080 5080
5070 -GRADF 5070
5060 / ILL py 5060
I II I
5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 3+00
5080 5080
GRADE
6 FILL
CT
6
5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00
STA 2+20III
5080 5080I
GRADE
5070 - pyy I 5070
5060 Fl L_
5060
I I5050 5050
-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 0+00
UTE ENERGYRIFFIN & ASSOCIATES, INC. ULT 12-5-4-2E
(son se2-so28 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM HORZ. 1"= 60' VERT. 1"=20'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'F/GURE#2 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
GRADE
5060 FILL.---- - I
' CUT5060
I I I II I I I
5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 4+00
5080 5080
5070 -GRADF 5070
5060 / ILL py 5060
I II I
5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 3+00
5080 5080
GRADE
6 FILL
CT
6
5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00
STA 2+20III
5080 5080I
GRADE
5070 - pyy I 5070
5060 Fl L_
5060
I I5050 5050
-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 0+00
UTE ENERGYRIFFIN & ASSOCIATES, INC. ULT 12-5-4-2E
(son se2-so28 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM HORZ. 1"= 60' VERT. 1"=20'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'F/GURE#2 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
GRADE
5060 FILL.---- - I
' CUT5060
I I I II I I I
5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 4+00
5080 5080
5070 -GRADF 5070
5060 / ILL py 5060
I II I
5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 3+00
5080 5080
GRADE
6 FILL
CT
6
5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00
STA 2+20III
5080 5080I
GRADE
5070 - pyy I 5070
5060 Fl L_
5060
I I5050 5050
-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 0+00
UTE ENERGYRIFFIN & ASSOCIATES, INC. ULT 12-5-4-2E
(son se2-so28 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM HORZ. 1"= 60' VERT. 1"=20'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'F/GURE#2 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
API Well Number: 43047540820000
GRADE
5060 FILL.---- - I
' CUT5060
I I I II I I I
5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 4+00
5080 5080
5070 -GRADF 5070
5060 / ILL py 5060
I II I
5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 3+00
5080 5080
GRADE
6 FILL
CT
6
5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00
STA 2+20III
5080 5080I
GRADE
5070 - pyy I 5070
5060 Fl L_
5060
I I5050 5050
-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00
STA 0+00
UTE ENERGYRIFFIN & ASSOCIATES, INC. ULT 12-5-4-2E
(son se2-so28 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM HORZ. 1"= 60' VERT. 1"=20'
REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'F/GURE#2 FINISHED ELEVATION: 5063.7'
RECEIVED: October 25,
RECEIVED: October 25, 2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±co / 5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'
/ ---
--
-----....._.
FINISHEDELEVATION 50
158' c. STA 4+00162'
ll / . O
I II
KAGE ' COMPLET/ONSP/T/ 140' X 100' X 12'
| 24, J8J Bb/s || 19,478 Bb/s | STA 3+00U WITH2' FREEBOARD \TOILET
/ 1.5 C 6.- / - -RESERVE P/T,
/ 100' X 60' X 12'// 9,JJ6 Bb/s /| 15 FLARE PIT
7,224 Bb/s/ iMTH22' FREEBOCARD
30 STA 2+20
PE RACKS
I / /
162' 148 STA 0+00S 14 56'57" E ' 310
-
·~" EXCE3S M TER AL PI
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEETf/TE ENERGYULT 12-5-4-2E
SECTION 5, T4S, R2ERIFFIN & ASSOCIATES, INC. ESTIMATED EARTHWORK
(307) 362-50281414 ELK ST., ROCK SPRINGS, WY82901
ITEM CUT FILL TOPSOIL EXCESSDRAWN:7/9/12-TCM SCALE: 1"=80' PAD 13,351CY 8,482CY 2,347CY 2,522CY
REVISED: NA DRG JOB No. 19386 PIT 7,011 CY 7,011 CY
FIGURE#3 TOTALS 20,362 CY 8,482 CY 2,347 CY 9,533 CY
RECEIVED: October 25,
API Well Number: 43047540820000
APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±co / 5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'
/ ---
--
-----....._.
FINISHEDELEVATION 50
158' c. STA 4+00162'
ll / . O
I II
KAGE ' COMPLET/ONSP/T/ 140' X 100' X 12'
| 24, J8J Bb/s || 19,478 Bb/s | STA 3+00U WITH2' FREEBOARD \TOILET
/ 1.5 C 6.- / - -RESERVE P/T,
/ 100' X 60' X 12'// 9,JJ6 Bb/s /| 15 FLARE PIT
7,224 Bb/s/ iMTH22' FREEBOCARD
30 STA 2+20
PE RACKS
I / /
162' 148 STA 0+00S 14 56'57" E ' 310
-
·~" EXCE3S M TER AL PI
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEETf/TE ENERGYULT 12-5-4-2E
SECTION 5, T4S, R2ERIFFIN & ASSOCIATES, INC. ESTIMATED EARTHWORK
(307) 362-50281414 ELK ST., ROCK SPRINGS, WY82901
ITEM CUT FILL TOPSOIL EXCESSDRAWN:7/9/12-TCM SCALE: 1"=80' PAD 13,351CY 8,482CY 2,347CY 2,522CY
REVISED: NA DRG JOB No. 19386 PIT 7,011 CY 7,011 CY
FIGURE#3 TOTALS 20,362 CY 8,482 CY 2,347 CY 9,533 CY
RECEIVED: October 25,
API Well Number: 43047540820000
APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±co / 5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'
/ ---
--
-----....._.
FINISHEDELEVATION 50
158' c. STA 4+00162'
ll / . O
I II
KAGE ' COMPLET/ONSP/T/ 140' X 100' X 12'
| 24, J8J Bb/s || 19,478 Bb/s | STA 3+00U WITH2' FREEBOARD \TOILET
/ 1.5 C 6.- / - -RESERVE P/T,
/ 100' X 60' X 12'// 9,JJ6 Bb/s /| 15 FLARE PIT
7,224 Bb/s/ iMTH22' FREEBOCARD
30 STA 2+20
PE RACKS
I / /
162' 148 STA 0+00S 14 56'57" E ' 310
-
·~" EXCE3S M TER AL PI
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEETf/TE ENERGYULT 12-5-4-2E
SECTION 5, T4S, R2ERIFFIN & ASSOCIATES, INC. ESTIMATED EARTHWORK
(307) 362-50281414 ELK ST., ROCK SPRINGS, WY82901
ITEM CUT FILL TOPSOIL EXCESSDRAWN:7/9/12-TCM SCALE: 1"=80' PAD 13,351CY 8,482CY 2,347CY 2,522CY
REVISED: NA DRG JOB No. 19386 PIT 7,011 CY 7,011 CY
FIGURE#3 TOTALS 20,362 CY 8,482 CY 2,347 CY 9,533 CY
RECEIVED: October 25,
API Well Number: 43047540820000
APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±co / 5.2% GRADE OF A NORTHERLY SLOPE
UNGRADED ELEVATION: 5064.2'
/ ---
--
-----....._.
FINISHEDELEVATION 50
158' c. STA 4+00162'
ll / . O
I II
KAGE ' COMPLET/ONSP/T/ 140' X 100' X 12'
| 24, J8J Bb/s || 19,478 Bb/s | STA 3+00U WITH2' FREEBOARD \TOILET
/ 1.5 C 6.- / - -RESERVE P/T,
/ 100' X 60' X 12'// 9,JJ6 Bb/s /| 15 FLARE PIT
7,224 Bb/s/ iMTH22' FREEBOCARD
30 STA 2+20
PE RACKS
I / /
162' 148 STA 0+00S 14 56'57" E ' 310
-
·~" EXCE3S M TER AL PI
BHLBEFORE DIGGING
CALL FORTJTILITY LINE LOCATION
NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE
RESPONSIBILITY OF THE USER. SCALE FEETf/TE ENERGYULT 12-5-4-2E
SECTION 5, T4S, R2ERIFFIN & ASSOCIATES, INC. ESTIMATED EARTHWORK
(307) 362-50281414 ELK ST., ROCK SPRINGS, WY82901
ITEM CUT FILL TOPSOIL EXCESSDRAWN:7/9/12-TCM SCALE: 1"=80' PAD 13,351CY 8,482CY 2,347CY 2,522CY
REVISED: NA DRG JOB No. 19386 PIT 7,011 CY 7,011 CY
FIGURE#3 TOTALS 20,362 CY 8,482 CY 2,347 CY 9,533 CY
RECEIVED: October 25,
RECEIVED: October 30, 2013
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01
08
36
04
07
09
05
3231
06
12
33
RANDLETT 24304730253
DEEP CREEK8-314304740032
COLEMAN TRIBAL7-8-4-2E4304751496
UTE TRIBAL6-32-3-2E4304751555
UTE TRIBAL1-5-4-2E4304751556
UTE TRIBAL10-5-4-2E4304751557
UTE TRIBAL6-9-4-2E4304751558
ULT 10-6-4-2E4304751569ULT 12-6-4-2E
4304751571
ULT 14-6-4-2E4304751572
ULT 16-6-4-2E4304751573
ULT 11-5-4-2E4304751574
DEEP CREEK13-32-3-2E4304751575
ULT14-31-3-2E4304751576
ULT16-36-3-1E4304751580
ULT12-31-3-2E4304751585
ULT 6-31-3-2E4304751661
DEEP CREEK11-32-3-2E4304751664
COLEMAN TRIBAL1-8-4-2E4304751727
COLEMAN TRIBAL7-7-4-2E
4304751728
DEEP CREEKTRIBAL 9-7-4-2E4304751729
COLEMAN TRIBAL3-8-4-2E4304751730
DEEP CREEKTRIBAL 13-8-4-2E4304751732
COLEMAN TRIBAL5-7-4-2E4304751733
DEEP CREEKTRIBAL 15-8-4-2E4304751734
ULT 9-36-3-1E4304751900
ULT 9-6-4-2E4304751916
ULT 15-6-4-2E4304751928
ULT 8-36-3-1E4304751931
ULT 11-6-4-2E4304751932
ULT 13-6-4-2E4304751934
COLEMAN TRIBAL1-7-4-2E4304751937
COLEMAN TRIBAL3-7-4-2E4304752002
DEEP CREEKTRIBAL 9-8-4-2E4304752007DEEP CREEK
TRIBAL 11-8-4-2E4304752008
DEEP CREEKTRIBAL 11-7-4-2E4304752009
DEEP CREEKTRIBAL 15-7-4-2E4304752010
UTE TRIBAL15-32-3-2E4304752195
UTE TRIBAL16-5-4-2E4304752196
UTE TRIBAL11-4-4-2E4304752197
UTE TRIBAL13-4-4-2E4304752198
UTE TRIBAL14-4-4-2E4304752199
UTE TRIBAL4-9-4-2E4304752200
DEEP CREEKTRIBAL 3-5-4-2E4304752223
DEEP CREEKTRIBAL 5-5-4-2E4304752224
DEEP CREEKTRIBAL 4-5-4-2E4304752225
DEEP CREEKTRIBAL 6-5-4-2E4304752226
DEEP CREEK13-9-4-2E4304752410
DEEP CREEK11-9-4-2E4304752415
ULT 14-5-4-2E4304752417
BOWERS1-6-4-2E4304752419
BOWERS2-6-4-2E4304752420
BOWERS3-6-4-2E4304752421
ULT 13-5-4-2E4304752423
BOWERS5-6-4-2E4304752427
BOWERS6-6-4-2E4304752428
BOWERS7-6-4-2E4304752430
BOWERS8-6-4-2E4304752431
BOWERS4-6-4-2E4304752432
DEEP CREEK12-9-4-2E4304752440
UTE TRIBAL1-1-4-1E4304752441
UTE TRIBAL9-1-4-1E4304752443
DEEP CREEK14-9-4-2E4304752445
DEEP CREEK12-32-3-2E4304752453
DEEP CREEK14-32-3-2E4304752455
COLEMAN TRIBAL2-7-4-2E4304752472
COLEMAN TRIBAL4-7-4-2E4304752473
COLEMAN TRIBAL6-7-4-2E4304752474
COLEMAN TRIBAL8-7-4-2E4304752475
DEEP CREEKTRIBAL 10-7-4-2E4304752476
DEEP CREEKTRIBAL 12-7-4-2E4304752477
DEEP CREEKTRIBAL 14-7-4-2E4304752478
DEEP CREEKTRIBAL 16-7-4-2E4304752479
COLEMAN TRIBAL2-8-4-2E4304752480
COLEMAN TRIBAL4-8-4-2E4304752481
DEEP CREEKTRIBAL 14-8-4-2E4304752482
DEEP CREEKTRIBAL 12-8-4-2E4304752483
COLEMAN TRIBAL6-8-4-2E4304752484
COLEMAN TRIBAL8-8-4-2E4304752485
DEEP CREEKTRIBAL 16-8-4-2E4304752486
DEEP CREEKTRIBAL 10-8-4-2E4304752487
UTE TRIBAL1-12-4-1E4304752517
ULT 5-31-3-2E4304752956
ULT11-31-3-2E4304752957
ULT13-31-3-2E4304752958
DEEP CREEK7-31-3-2E4304752984
UTE ENERGY16-31-3-2E4304752985
UTE ENERGY15-31-3-2E4304752986
Ute Tribal7-5-4-2E4304753782
Ute Tribal2-5-4-2E4304753783
Ute Tribal10-32-3-2E4304753784
Ute Tribal5-32-3-2E4304753785
Ute Tribal3-9-4-2E
4304753787
Ute Tribal15-5-4-2E4304753788
Ute Tribal9-5-4-2E4304753789
Ute Tribal5-9-4-2E4304753790
Ute Tribal8-5-4-2E4304753791
Deep CreekTribal 5-4-4-2E4304754005
Deep CreekTribal 12-4-4-2E4304754006
Deep CreekTribal 15-4-4-2E
4304754008
ULT 12-5-4-2E4304754082
Deep Creek5-33-3-2E4304754087
Deep Creek6-33-3-2E
4304754094
Deep Creek7-32-3-2E4304754095
Deep Creek8-32-3-2E
4304754099
R A N D L E T TR A N D L E T TW A T E R F L O O DW A T E R F L O O D
P R O J E C TP R O J E C T
Map Produced by Diana Mason
F1,700 0 1,700850 Feet
1:16,807
Wells QueryStatus
APD - Aproved Permit
H DRL - Spuded (Drilling Commenced)
4 GIW - Gas Injection
!) GS - Gas Storage
! LOC - New Location
7 OPS - Operation Suspended
ª PA - Plugged Abandoned
* PGW - Producing Gas Well
' POW - Producing Oil Well
¸ SGW - Shut-in Gas Well
· SOW - Shut-in Oil Well
6 TA - Temp. Abandoned
" TW - Test Well
¸ WDW - Water Disposal
¸ WIW - Water Injection Well
=) WSW - Water Supply Well
UnitsSTATUS
ACTIVE
EXPLORATORY
GAS STORAGE
NF PP OIL
NF SECONDARY
PI OIL
PP GAS
PP GEOTHERML
PP OIL
SECONDARY
TERMINATED
TOOELE
SAN JUAN
MILLARD
KANE
JUAB
IRON
EMERY
UINTAH
BOX ELDER
GARFIELD
GRAND
UTAH
WAYNEBEAVER
DUCHESNE
SEVIER
SUMMIT
RICH
WASHINGTON
CARBON
SANPETE
CACHE
PIUTE
DAVIS
WASATCH
WEBER
SALT LAKE
DAGGETT
MORGAN
Location Map
API Number: 4304754082Well Name: ULT 12-5-4-2E Township: T04.0S Range: R02.0E Section: 05 Meridian: U
Operator: CRESCENT POINT ENERGY U.S. CORP
Map Prepared: 10/30/2013
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
ULT8-36 3-1E ULT6-31-3-2E DEEP CREEK Ute Tribal UTE TRIBAL Deep Creek D CreeDeep Creek
4304751 31 443LO457-532193562E4304751661 443301472E84 EPCREEK +5-3302473E85 33024755
e433024734E95e 43
3p73302 API Number: 4304754082430474(032 De8e3p2 2ek Well Name: ULT 12-5-4-2E
ULT 1 31-3-2E DEEP C EEK Ute Tribal Township: TO4.0S Range: RO2.0E Section: 05 Meridian: UULT9-36 3-1E 12-31-3-2E 4304752957 DEEP CREEK 11-32-3- 10-32-3-2E
Operator: CRESCENT POINT ENERGY U.S. CORP4304751 00 4304751585 12-32-3-2E 4304751064 4304753784
36 31 4304752453 3332 Map Prepared: 10/30/2013
9
Map Produced by Diana Mason
ULT ULT4LT31-3-2E UTE ENE GY DEEP CREEK DEEP CI,EEK UTE TRIBAL
0345 0
0345
29E8 4304751576 R3A0N4D3L0E25320341322
5034'5 5E5 034'5 E5 034
5 5
TE ENERGY15-31-3-2E4304752986 Welle Query Units
UTE TRI AL BOWERS BOWERS BOWERS DEEP CREEK DEEP CREEK Ute Tribal5E T2RI AL sta s
APo-Aprovec Permit AcnvE
3 4 5 41 4E2RES 3604 5E421
3 45E420
3 45E419
3RIBA5L2422554-2ERIBA5L2322534-2E 3504 5E783 4304751 56 DRL spude ori ngcommenceci ExPSLSosAvoav
4304752432 Deep Creek os osss NFPPat
BOWERS BOWERS BOWERS 8-E2 DEEP CREEK DEEP CREEK 7 4
bEal
4
5br30bal75544452E oNDARY
5-6-4-2E 6-6-4-2E 7-6-4-2E 430475 431 TRIBAL5-5-4-2E TRIBAL6-5-4-2E 4304753782 4 sposoyeesse4304752427 4304752428 4304752430 + 4304752224 4304752226 * 04 PPat
06 05 sEcoNDARY
Ute Triba Deep Creek UTE TRIBAL TERMiNATED
UTETRIBAL 9-5-4-2E Tribal12-4-4-2E30 7
2Egyve neone
UTE T1R ALULT 12-6-4-2E ULT 11-6-4-2E
43LO417051654692E43LO756-49-2 3LO417254504822E
ULT 11-5-4-2E0547
574304753 89 4304754006
014304752- 43 4304751571 4304751932 + 4304751574 se
Ute Tribal UTE TRIBAL SUPP
15-5-4-2E UTE T IBAL UTE TRIBAL 14-4-4-2E4304753788 16-5-4- E
13-4-4-2E4304752199
ULT13-6-4-2E ULT14-6-4-2E ULT15-6-4-2E ULT16-64-2E 43LO41352544232E43LO4174525-72E 43047 2196 44304752198 4
4304751934 4304751572 4304751928 4304751:·73 4 * Deep Cree Box ELDERic
Location Map4 +
COLENAN TRIBAL UTE TRIBAL 39-Tri2bal430475400
1-R-4-2: 4-9-4-2E 4304753787
UTE TRI IAL COLEMAN TRIBAL COLEMAN TRIBAL COLE TRIBAL_LEMANTRIBAL 4304751727 4304752200 vooEu
1-12-4-1: 4-7-4-2E 3-7-4-2E 1-7-4-2E 4304751730 COLEMAN TRIBAL uvAs iNTAH
4304752: 17 4304752473 4304752002 *LE2MANTRIBAL
4304751 37 *LE2MANTRIBAL 2-3
45E480 auAs
cAasoN
4304752472 4304752481 Ute Tribal UTE TRIBALCOLEMAN TRIBAL 5-9-4-2E 6-9-4-2E
MiLLARD
COLEMAN IBAL 7-8-4-2E COLEMAH TRIBAL 4304753790 4304751558 EMERY GR^ND
COLEMAN TRIBAL COLEMAN TRIBAL 8-7-4-2E COLEMAN TRIBAL 4304751496 *8-8-4-2E sEviER
5-7-4-2E 7-7-4-2E4304752475 +6-8-4-2E 4304752465
4304751733 4 07 4304751728 9 A N LETT 4304752484 DEEP CREEKBEAvER PiuTE wAvNE
12
COL44EMAN74TRIBALWATREORLFELCOOD og
43RIBA5L2140878-4-2EDREE E8E4K2E
EEP4-C2REEEOKDE9EP4- EEK
IRON GARFiELD
NauAN
DEEPCREEK DEEPCREEK DEEPCI EEKTDREEPL
18-K4-2E 4304752007 4304752440 44304752415 wAsHiNovoN mas
TRIBAL12-7-4-2E TRIBAL11-7-4-2E TRIBALE-7-4-2E DEEPCREEK 43047520084304752477 4304752009 4 4304751 29 *TRIBAL 12-8-4-2EDEEP CREEK 4304752483TRIBAL 10-7-4-2E DEEP CREEK DEEP CREEK
TDREEP
4EEK4-2E430D4RB2A4L
5EEK4-2ETDREEP6
-K4-2EIDREEP3
-K4-2 R5
4E K4-2E R 5L 5 -K4-2+R \5 6
-K4-2E
04722E10 04722E45
1700 eso a 17ooFeet
4304752478 4304752010 *4304752 i79 43047517321:16,807
RECEIVED: October 30,
API Well Number: 43047540820000
ULT8-36 3-1E ULT6-31-3-2E DEEP CREEK Ute Tribal UTE TRIBAL Deep Creek D CreeDeep Creek
4304751 31 443LO457-532193562E4304751661 443301472E84 EPCREEK +5-3302473E85 33024755
33024734E95* 43
3p73302 API Number: 4304754082430474(032 De8e3p2 2ek Well Name: ULT 12-5-4-2E
ULT 1 31-3-2E DEEP C EEK Ute Tribal Township: TO4.0S Range: RO2.0E Section: 05 Meridian: UULT9-36 3-1E 12-31-3-2E 4304752957 DEEP CREEK 11-32-3- 10-32-3-2E
Operator: CRESCENT POINT ENERGY U.S. CORP4304751 00 4304751585 12-32-3-2E 4304751064 4304753784
36 31 4304752453 3332 Map Prepared: 10/30/2013
9
Map Produced by Diana Mason
ULT ULT4LT31-3-2E UTE ENE GY DEEP CREEK DEEP CI,EEK UTE TRIBAL
0345 0
0345
29E8 4304751576 R3A0N4D3L0E25320341322
5034'5 5E5 034'5 E5 034
5 5
TE ENERGY15-31-3-2E4304752986 Welle Query Units
UTE TRI AL BOWERS BOWERS BOWERS DEEP CREEK DEEP CREEK Ute Tribal5E T2RI AL sta s
APo-Aprovec Permit AcnvE
3 4 5 41 4E2RES 3604 5E421
3 45E420
3 45E419
3RIBA5L2422554-2ERIBA5L2322534-2E _35045E783 4304751 56 o DRL spude ori ngcommenceci ExPSLSosAvoav
4304752432 Deep Creek os ossstoege NFPPat
Tribal 5-4-4-2E NF sEcoNDARY
Ute Tribal Ute Tribal 4304754005 e Loc New tocation
BOWERS BOWERS BOWERS 8-E2 DEEPCREEK DEEPCREEK 7-5-4-2E
3 45E
PPoAs
5-6-4-2E 6-6-4-2E 7-6-4-2E 430475 431 TRIBAL5-5-4-2E TRIBAL6-5-4-2E 4304753782 4 sposoyeesse4304752427 4304752428 4304752430 + 4304752224 4304752226 * 04 PPat
06 05 sEcoNDARY
Ute Triba Deep Creek UTE TRIBAL TERMiNATED
UTETRIBAL 9-5-4-2E Tribal12-4-4-2E30 7
2Egyo Te neone
UTE T1R ALULT 12-6-4-2E ULT 11-6-4-2E
43LO417051654692E43LO756-49-2 3LO417254504822E
ULT 11-5-4-2E0547
574304753 89 œ4304754006
014304752- 43 4304751571 4304751932 + 4304751574 se
Ute Tribal UTE TRIBAL SUPP
15-5-4-2E UTE T IBAL UTE TRIBAL 14-4-4-2E4304753788 16-5-4- E
13-4-4-2E4304752199 ,
ULT13-6-4-2E ULT14-6-4-2E ULT15-6-4-2E ULT16-64-2E 43LO41352544232E43LO4174525-72E 43047 2196 44304752198 4
4304751934 4304751572 4304751928 4304751:·73 4 * Deep Cree Box ELDERic
Location Map4 +
COLENANTRIBAL UTETRIBAL39Tri2bal430475400
1-R-4-2: 4-9-4-2E 4304753787
UTE TRI IAL COLEMAN TRIBAL COLEMAN TRIBAL COLE TRIBAL_LEMANTRIBAL 4304751727 4304752200 vooEu
1-12-4-1: 4-7-4-2E 3-7-4-2E 1-7-4-2E 4304751730 COLEMAN TRIBAL uvAs iNTAH
4304752: 17 4304752473 4304752002 *LE2MANTRIBAL
4304751 37 *LE2MANTRIBAL 2-3
45E480 auAs
cAasoN
4304752472 4304752481 Ute Tribal UTE TRIBALCOLEMAN TRIBAL 5-9-4-2E 6-9-4-2E
MiLLARD
COLEMAN IBAL 7-8-4-2E COLEMAH TRIBAL 4304753790 4304751558 EMERY GR^ND
COLEMAN TRIBAL COLEMAN TRIBAL 8-7-4-2E COLEMAN TRIBAL 4304751496 *8-8-4-2E sEviER
5-7-4-2E 7-7-4-2E4304752475 +6-8-4-2E 4304752465
4304751733 4 07 4304751728 9 A N LETT 4304752484 DEEP CREEKBEAvER PiuTE wAvNE
12
COL44EMAN74TRIBALWATREORLFELCOOD og
43RIBA5L2140878-4-2EDREE E8E4K2E
EEP4-C2REEEOKDE9EP4- EEK
IRON GARFiELD
NauAN
DEEPCREEK DEEPCREEK DEEPCI EEKTDREEPL
18-K4-2E 4304752007 4304752440 44304752415 wAsHiNovoN mas
TRIBAL12-7-4-2E TRIBAL11-7-4-2E TRIBALE-7-4-2E DEEPCREEK 43047520084304752477 4304752009 4 4304751 29 *TRIBAL 12-8-4-2EDEEP CREEK 4304752483TRIBAL 10-7-4-2E DEEP CREEK DEEP CREEK
TDREEP
4EEK4-2E430D4RB2A4L
5EEK4-2ETDREEP6
-K4-2EIDREEP3
-K4-2 R5
4E K4-2E R 5L 5 -K4-2+R \5 6
-K4-2E
04722E10 04722E45
1700 eso a 17ooFeet
4304752478 4304752010 *4304752 i79 43047517321:16,807
RECEIVED: October 30,
API Well Number: 43047540820000
ULT8-36 3-1E ULT6-31-3-2E DEEP CREEK Ute Tribal UTE TRIBAL Deep Creek D CreeDeep Creek
4304751 31 443LO457-532193562E4304751661 443301472E84 EPCREEK +5-3302473E85 33024755
33024734E95* 43
3p73302 API Number: 4304754082430474(032 De8e3p2 2ek Well Name: ULT 12-5-4-2E
ULT 1 31-3-2E DEEP C EEK Ute Tribal Township: TO4.0S Range: RO2.0E Section: 05 Meridian: UULT9-36 3-1E 12-31-3-2E 4304752957 DEEP CREEK 11-32-3- 10-32-3-2E
Operator: CRESCENT POINT ENERGY U.S. CORP4304751 00 4304751585 12-32-3-2E 4304751064 4304753784
36 31 4304752453 3332 Map Prepared: 10/30/2013
9
Map Produced by Diana Mason
ULT ULT4LT31-3-2E UTE ENE GY DEEP CREEK DEEP CI,EEK UTE TRIBAL
0345 0
0345
29E8 4304751576 R3A0N4D3L0E25320341322
5034'5 5E5 034'5 E5 034
5 5
TE ENERGY15-31-3-2E4304752986 Welle Query Units
UTE TRI AL BOWERS BOWERS BOWERS DEEP CREEK DEEP CREEK Ute Tribal5E T2RI AL sta s
APo-Aprovec Permit AcnvE
3 4 5 41 4E2RES 3604 5E421
3 45E420
3 45E419
3RIBA5L2422554-2ERIBA5L2322534-2E _35045E783 4304751 56 o DRL spude ori ngcommenceci ExPSLSosAvoav
4304752432 Deep Creek os ossstoege NFPPat
Tribal 5-4-4-2E NF sEcoNDARY
Ute Tribal Ute Tribal 4304754005 e Loc New tocation
BOWERS BOWERS BOWERS 8-E2 DEEPCREEK DEEPCREEK 7-5-4-2E
3 45E
PPoAs
5-6-4-2E 6-6-4-2E 7-6-4-2E 430475 431 TRIBAL5-5-4-2E TRIBAL6-5-4-2E 4304753782 4 sposoyeesse4304752427 4304752428 4304752430 + 4304752224 4304752226 * 04 PPat
06 05 sEcoNDARY
Ute Triba Deep Creek UTE TRIBAL TERMiNATED
UTETRIBAL 9-5-4-2E Tribal12-4-4-2E30 7
2Egyo Te neone
UTE T1R ALULT 12-6-4-2E ULT 11-6-4-2E
43LO417051654692E43LO756-49-2 3LO417254504822E
ULT 11-5-4-2E0547
574304753 89 œ4304754006
014304752- 43 4304751571 4304751932 + 4304751574 se
Ute Tribal UTE TRIBAL SUPP
15-5-4-2E UTE T IBAL UTE TRIBAL 14-4-4-2E4304753788 16-5-4- E
13-4-4-2E4304752199 ,
ULT13-6-4-2E ULT14-6-4-2E ULT15-6-4-2E ULT16-64-2E 43LO41352544232E43LO4174525-72E 43047 2196 44304752198 4
4304751934 4304751572 4304751928 4304751:·73 4 * Deep Cree Box ELDERic
Location Map4 +
COLENANTRIBAL UTETRIBAL39Tri2bal430475400
1-R-4-2: 4-9-4-2E 4304753787
UTE TRI IAL COLEMAN TRIBAL COLEMAN TRIBAL COLE TRIBAL_LEMANTRIBAL 4304751727 4304752200 vooEu
1-12-4-1: 4-7-4-2E 3-7-4-2E 1-7-4-2E 4304751730 COLEMAN TRIBAL uvAs iNTAH
4304752: 17 4304752473 4304752002 *LE2MANTRIBAL
4304751 37 *LE2MANTRIBAL 2-3
45E480 auAs
cAasoN
4304752472 4304752481 Ute Tribal UTE TRIBALCOLEMAN TRIBAL 5-9-4-2E 6-9-4-2E
MiLLARD
COLEMAN IBAL 7-8-4-2E COLEMAH TRIBAL 4304753790 4304751558 EMERY GR^ND
COLEMAN TRIBAL COLEMAN TRIBAL 8-7-4-2E COLEMAN TRIBAL 4304751496 *8-8-4-2E sEviER
5-7-4-2E 7-7-4-2E4304752475 +6-8-4-2E 4304752465
4304751733 4 07 4304751728 9 A N LETT 4304752484 DEEP CREEKBEAvER PiuTE wAvNE
12
COL44EMAN74TRIBALWATREORLFELCOOD og
43RIBA5L2140878-4-2EDREE E8E4K2E
EEP4-C2REEEOKDE9EP4- EEK
IRON GARFiELD
NauAN
DEEPCREEK DEEPCREEK DEEPCI EEKTDREEPL
18-K4-2E 4304752007 4304752440 44304752415 wAsHiNovoN mas
TRIBAL12-7-4-2E TRIBAL11-7-4-2E TRIBALE-7-4-2E DEEPCREEK 43047520084304752477 4304752009 4 4304751 29 *TRIBAL 12-8-4-2EDEEP CREEK 4304752483TRIBAL 10-7-4-2E DEEP CREEK DEEP CREEK
TDREEP
4EEK4-2E430D4RB2A4L
5EEK4-2ETDREEP6
-K4-2EIDREEP3
-K4-2 R5
4E K4-2E R 5L 5 -K4-2+R \5 6
-K4-2E
04722E10 04722E45
1700 eso a 17ooFeet
4304752478 4304752010 *4304752 i79 43047517321:16,807
RECEIVED: October 30,
API Well Number: 43047540820000
ULT8-36 3-1E ULT6-31-3-2E DEEP CREEK Ute Tribal UTE TRIBAL Deep Creek D CreeDeep Creek
4304751 31 443LO457-532193562E4304751661 443301472E84 EPCREEK +5-3302473E85 33024755
33024734E95* 43
3p73302 API Number: 4304754082430474(032 De8e3p2 2ek Well Name: ULT 12-5-4-2E
ULT 1 31-3-2E DEEP C EEK Ute Tribal Township: TO4.0S Range: RO2.0E Section: 05 Meridian: UULT9-36 3-1E 12-31-3-2E 4304752957 DEEP CREEK 11-32-3- 10-32-3-2E
Operator: CRESCENT POINT ENERGY U.S. CORP4304751 00 4304751585 12-32-3-2E 4304751064 4304753784
36 31 4304752453 3332 Map Prepared: 10/30/2013
9
Map Produced by Diana Mason
ULT ULT4LT31-3-2E UTE ENE GY DEEP CREEK DEEP CI,EEK UTE TRIBAL
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1700 eso a 17ooFeet
4304752478 4304752010 *4304752 i79 43047517321:16,807
RECEIVED: October 30,
RECEIVED: January 23, 2014
BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000
Well Name CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000
String Cond Surf Prod
Casing Size(") 16.000 8.625 5.500
Setting Depth (TVD) 4 0 1000 8006
Previous Shoe Setting Depth (TVD) 0 4 0 1000
Max Mud Weight (ppg) 8.3 8.3 10.0
BOPE Proposed (psi) 0 500 3000
Casing Internal Yield (psi) 1000 2950 7740
Operators Max Anticipated Pressure (psi) 4163 10.0
Calculations Cond String 1 6 . 0 0 0 "
Max BHP (psi) .052*Setting Depth*MW= 1 7
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 1 2 NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 8 NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 8 NO
Required Casing/BOPE Test Pressure= 4 0 p s i
*Max Pressure Allowed @ Previous Casing Shoe= 0 psi *Assumes 1psi/f t frac gradient
Calculations Surf String 8 . 6 2 5 "
Max BHP (psi) .052*Setting Depth*MW= 432
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 312 YES air/mist
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 212 YES OK
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 221 NO OK
Required Casing/BOPE Test Pressure= 1000 p s i
*Max Pressure Allowed @ Previous Casing Shoe= 4 0 psi *Assumes 1psi/f t frac gradient
Calculations Prod String 5 . 5 0 0 "
Max BHP (psi) .052*Setting Depth*MW= 4163
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 3202 NO 3M BOPE, rotating head, annular preventer,
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 2402 YES dbl rams, choke & kill lines
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 2622 NO OK
Required Casing/BOPE Test Pressure= 3000 p s i
*Max Pressure Allowed @ Previous Casing Shoe= 1000 psi *Assumes 1psi/f t frac gradient
Calculations String "
Max BHP (psi) .052*Setting Depth*MW=
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= NO
Required Casing/BOPE Test Pressure= p s i
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes 1psi/f t frac gradient
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000
Well Name CRESCENT POINT ENERGY U.S. CORP ULT 12-5 4-2E 43047540820
String Cond Surf Prod
Casing Size(") 16.000 8.625 5.500
Setting Depth (TVD) 40 1000 8006
Previous Shoe Setting Depth (TVD) 0 40 1000
Max Mud Weight (ppg) 8.3 8.3 10.0
BOPE Proposed (psi) o Soo 3000
Casing Internal Yield (psi) 1000 2950 7740
Operators Max Anticipated Pressure (psi) 4163 10.0
Calculations Cond String 16.000 "Max BHP (psi) .052*Setting Depth*MW=
17
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=12 NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=8 NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=8 NO
Required Casing/BOPE Test Pressure=40 psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
Calculations Surf String 8.625 "Max BHP (psi) .052*Setting Depth*MW=
432
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=312 air/mist
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=212 OK
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=221 NO OK
Required Casing/BOPE Test Pressure=1000 psi
*Max Pressure Allowed @ Previous Casing Shoe=40 psi *Assumes lpsi/ft frac gradient
Calculations Prod String 5.500 "Max BHP (psi) .052*Setting Depth*MW=
4163
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=3202 NO 3M BOPE, rotating head, annular preventer,
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=2402 dbl rams, choke & kill lines
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=2622 NO OK
Required Casing/BOPE Test Pressure=3000 psi
*Max Pressure Allowed @ Previous Casing Shoe=1000 psi *Assumes lpsi/ft frac gradient
Calculations String
Max BHP (psi) .052*Setting Depth*MW=
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=NO
Required Casing/BOPE Test Pressure= psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
RECEIVED: January 23,
API Well Number: 43047540820000
BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000
Well Name CRESCENT POINT ENERGY U.S. CORP ULT 12-5 4-2E 43047540820
String Cond Surf Prod
Casing Size(") 16.000 8.625 5.500
Setting Depth (TVD) 40 1000 8006
Previous Shoe Setting Depth (TVD) 0 40 1000
Max Mud Weight (ppg) 8.3 8.3 10.0
BOPE Proposed (psi) o Soo 3000
Casing Internal Yield (psi) 1000 2950 7740
Operators Max Anticipated Pressure (psi) 4163 10.0
Calculations Cond String 16.000 "Max BHP (psi) .052*Setting Depth*MW=
17
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=12 NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=8 NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=8 NO
Required Casing/BOPE Test Pressure=40 psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
Calculations Surf String 8.625 "Max BHP (psi) .052*Setting Depth*MW=
432
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=312 air/mist
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=212 OK
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=221 NO OK
Required Casing/BOPE Test Pressure=1000 psi
*Max Pressure Allowed @ Previous Casing Shoe=40 psi *Assumes lpsi/ft frac gradient
Calculations Prod String 5.500 "Max BHP (psi) .052*Setting Depth*MW=
4163
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=3202 NO 3M BOPE, rotating head, annular preventer,
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=2402 dbl rams, choke & kill lines
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=2622 NO OK
Required Casing/BOPE Test Pressure=3000 psi
*Max Pressure Allowed @ Previous Casing Shoe=1000 psi *Assumes lpsi/ft frac gradient
Calculations String
Max BHP (psi) .052*Setting Depth*MW=
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=NO
Required Casing/BOPE Test Pressure= psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
RECEIVED: January 23,
API Well Number: 43047540820000
BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000
Well Name CRESCENT POINT ENERGY U.S. CORP ULT 12-5 4-2E 43047540820
String Cond Surf Prod
Casing Size(") 16.000 8.625 5.500
Setting Depth (TVD) 40 1000 8006
Previous Shoe Setting Depth (TVD) 0 40 1000
Max Mud Weight (ppg) 8.3 8.3 10.0
BOPE Proposed (psi) o Soo 3000
Casing Internal Yield (psi) 1000 2950 7740
Operators Max Anticipated Pressure (psi) 4163 10.0
Calculations Cond String 16.000 "Max BHP (psi) .052*Setting Depth*MW=
17
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=12 NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=8 NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=8 NO
Required Casing/BOPE Test Pressure=40 psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
Calculations Surf String 8.625 "Max BHP (psi) .052*Setting Depth*MW=
432
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=312 air/mist
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=212 OK
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=221 NO OK
Required Casing/BOPE Test Pressure=1000 psi
*Max Pressure Allowed @ Previous Casing Shoe=40 psi *Assumes lpsi/ft frac gradient
Calculations Prod String 5.500 "Max BHP (psi) .052*Setting Depth*MW=
4163
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=3202 NO 3M BOPE, rotating head, annular preventer,
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=2402 dbl rams, choke & kill lines
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=2622 NO OK
Required Casing/BOPE Test Pressure=3000 psi
*Max Pressure Allowed @ Previous Casing Shoe=1000 psi *Assumes lpsi/ft frac gradient
Calculations String
Max BHP (psi) .052*Setting Depth*MW=
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=NO
Required Casing/BOPE Test Pressure= psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
RECEIVED: January 23,
API Well Number: 43047540820000
BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000
Well Name CRESCENT POINT ENERGY U.S. CORP ULT 12-5 4-2E 43047540820
String Cond Surf Prod
Casing Size(") 16.000 8.625 5.500
Setting Depth (TVD) 40 1000 8006
Previous Shoe Setting Depth (TVD) 0 40 1000
Max Mud Weight (ppg) 8.3 8.3 10.0
BOPE Proposed (psi) o Soo 3000
Casing Internal Yield (psi) 1000 2950 7740
Operators Max Anticipated Pressure (psi) 4163 10.0
Calculations Cond String 16.000 "Max BHP (psi) .052*Setting Depth*MW=
17
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=12 NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=8 NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=8 NO
Required Casing/BOPE Test Pressure=40 psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
Calculations Surf String 8.625 "Max BHP (psi) .052*Setting Depth*MW=
432
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=312 air/mist
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=212 OK
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=221 NO OK
Required Casing/BOPE Test Pressure=1000 psi
*Max Pressure Allowed @ Previous Casing Shoe=40 psi *Assumes lpsi/ft frac gradient
Calculations Prod String 5.500 "Max BHP (psi) .052*Setting Depth*MW=
4163
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=3202 NO 3M BOPE, rotating head, annular preventer,
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=2402 dbl rams, choke & kill lines
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=2622 NO OK
Required Casing/BOPE Test Pressure=3000 psi
*Max Pressure Allowed @ Previous Casing Shoe=1000 psi *Assumes lpsi/ft frac gradient
Calculations String
Max BHP (psi) .052*Setting Depth*MW=
BOPE Adequate For Drilling And Setting Casing at Depth?
MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=NO
MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=NO
*Can Full Expected Pressure Be Held At Previous Shoe?
Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=NO
Required Casing/BOPE Test Pressure= psi
*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient
RECEIVED: January 23,
RECEIVED: January 23, 2014
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
43047540820000 LT 12-5-4-2ECasing Schema ,
' oosurface -
Tocoo.Toco295.
8-5/8" SurfaceMW 8.3 1000. MDFrac 19.3
5-1/2" 'Production
MW 10. 8006.
API Well Number: 43047540820000
43047540820000 LT 12-5-4-2ECasing Schema ,
' oosurface -
Tocoo.Toco295.
8-5/8" SurfaceMW 8.3 1000. MDFrac 19.3
5-1/2" 'Production
MW 10. 8006.
API Well Number: 43047540820000
43047540820000 LT 12-5-4-2ECasing Schema ,
' oosurface -
Tocoo.Toco295.
8-5/8" SurfaceMW 8.3 1000. MDFrac 19.3
5-1/2" 'Production
MW 10. 8006.
API Well Number: 43047540820000
43047540820000 LT 12-5-4-2ECasing Schema ,
' oosurface -
Tocoo.Toco295.
8-5/8" SurfaceMW 8.3 1000. MDFrac 19.3
5-1/2" 'Production
MW 10. 8006.
RECEIVED: January 23, 2014
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-6-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Surface Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 8.300 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 88 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 100 ft
Burst:Design factor 1.00 Cement top: 295 ft
BurstMax anticipated surface
pressure: 880 psiInternal gradient: 0.120 psi/ft Tension: Non-directional string.Calculated BHP 1,000 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.70 (J)Annular backup: 1.50 ppg Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.50 (B) Re subsequent strings:
Next setting depth: 8,006 ftTension is based on buoyed weight. Next mud weight: 10.000 ppgNeutral point: 875 ft Next setting BHP: 4,159 psi
Fracture mud wt: 19.250 ppgFracture depth: 1,000 ftInjection pressure: 1,000 psi
Run Segment Nominal End True Vert Measured Drift Est.Seq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 1000 8.625 24.00 J-55 ST&C 1000 1000 7.972 5147
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 431 1370 3.178 922 2950 3.20 21 244 11.61 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas &Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 1000 ft, a mud weight of 8.3 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-6-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Surface Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 8.300 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 88 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 100 ft
Burst:Design factor 1.00 Cement top: 295 ft
BurstMax anticipated surface
pressure: 880 psiInternal gradient: 0.120 psi/ft Tension: Non-directional string.Calculated BHP 1,000 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.70 (J)Annular backup: 1.50 ppg Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.50 (B) Re subsequent strings:
Next setting depth: 8,006 ftTension is based on buoyed weight. Next mud weight: 10.000 ppgNeutral point: 875 ft Next setting BHP: 4,159 psi
Fracture mud wt: 19.250 ppgFracture depth: 1,000 ftInjection pressure: 1,000 psi
Run Segment Nominal End True Vert Measured Drift Est.Seq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 1000 8.625 24.00 J-55 ST&C 1000 1000 7.972 5147
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 431 1370 3.178 922 2950 3.20 21 244 11.61 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas &Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 1000 ft, a mud weight of 8.3 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-6-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Surface Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 8.300 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 88 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 100 ft
Burst:Design factor 1.00 Cement top: 295 ft
BurstMax anticipated surface
pressure: 880 psiInternal gradient: 0.120 psi/ft Tension: Non-directional string.Calculated BHP 1,000 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.70 (J)Annular backup: 1.50 ppg Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.50 (B) Re subsequent strings:
Next setting depth: 8,006 ftTension is based on buoyed weight. Next mud weight: 10.000 ppgNeutral point: 875 ft Next setting BHP: 4,159 psi
Fracture mud wt: 19.250 ppgFracture depth: 1,000 ftInjection pressure: 1,000 psi
Run Segment Nominal End True Vert Measured Drift Est.Seq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 1000 8.625 24.00 J-55 ST&C 1000 1000 7.972 5147
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 431 1370 3.178 922 2950 3.20 21 244 11.61 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas &Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 1000 ft, a mud weight of 8.3 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-6-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Surface Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 8.300 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 88 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 100 ft
Burst:Design factor 1.00 Cement top: 295 ft
BurstMax anticipated surface
pressure: 880 psiInternal gradient: 0.120 psi/ft Tension: Non-directional string.Calculated BHP 1,000 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.70 (J)Annular backup: 1.50 ppg Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.50 (B) Re subsequent strings:
Next setting depth: 8,006 ftTension is based on buoyed weight. Next mud weight: 10.000 ppgNeutral point: 875 ft Next setting BHP: 4,159 psi
Fracture mud wt: 19.250 ppgFracture depth: 1,000 ftInjection pressure: 1,000 psi
Run Segment Nominal End True Vert Measured Drift Est.Seq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 1000 8.625 24.00 J-55 ST&C 1000 1000 7.972 5147
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 431 1370 3.178 922 2950 3.20 21 244 11.61 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas &Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 1000 ft, a mud weight of 8.3 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
RECEIVED: January 23, 2014
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-5-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Production Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 10.000 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 186 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 1,000 ft
Burst:Design factor 1.00 Cement top: Surface
BurstMax anticipated surface
pressure: 2,398 psiInternal gradient: 0.220 psilft Tension: Non-directional string.Calculated BHP 4,159 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.80 (J)No backup mud specified. Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.60 (B)
Tension is based on buoyed weight.Neutral point: 6,792 ft
Run Segment Nominal End True Vert Measured Drift EstSeq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 8006 5.5 17.00 E-80 LT&C 8006 8006 4.767 264198
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 4159 6290 1.512 4159 7740 1.86 115.5 320 2.77 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas & Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 8006 ft, a mud weight of 10 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-5-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Production Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 10.000 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 186 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 1,000 ft
Burst:Design factor 1.00 Cement top: Surface
BurstMax anticipated surface
pressure: 2,398 psiInternal gradient: 0.220 psilft Tension: Non-directional string.Calculated BHP 4,159 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.80 (J)No backup mud specified. Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.60 (B)
Tension is based on buoyed weight.Neutral point: 6,792 ft
Run Segment Nominal End True Vert Measured Drift EstSeq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 8006 5.5 17.00 E-80 LT&C 8006 8006 4.767 264198
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 4159 6290 1.512 4159 7740 1.86 115.5 320 2.77 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas & Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 8006 ft, a mud weight of 10 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-5-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Production Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 10.000 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 186 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 1,000 ft
Burst:Design factor 1.00 Cement top: Surface
BurstMax anticipated surface
pressure: 2,398 psiInternal gradient: 0.220 psilft Tension: Non-directional string.Calculated BHP 4,159 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.80 (J)No backup mud specified. Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.60 (B)
Tension is based on buoyed weight.Neutral point: 6,792 ft
Run Segment Nominal End True Vert Measured Drift EstSeq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 8006 5.5 17.00 E-80 LT&C 8006 8006 4.767 264198
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 4159 6290 1.512 4159 7740 1.86 115.5 320 2.77 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas & Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 8006 ft, a mud weight of 10 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
API Well Number: 43047540820000
Well name: 43047540820000 ULT 12-5-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Production Project ID:
43-047-54082Location: UINTAH COUNTY
Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No
Mud weight: 10.000 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 186 °F
Temperature gradient: 1.40 °F/100ftMinimum section length: 1,000 ft
Burst:Design factor 1.00 Cement top: Surface
BurstMax anticipated surface
pressure: 2,398 psiInternal gradient: 0.220 psilft Tension: Non-directional string.Calculated BHP 4,159 psi 8 Round STC: 1.80 (J)
8 Round LTC: 1.80 (J)No backup mud specified. Buttress: 1.60 (J)
Premium: 1.50 (J)Body yield: 1.60 (B)
Tension is based on buoyed weight.Neutral point: 6,792 ft
Run Segment Nominal End True Vert Measured Drift EstSeq Length Size Weight Grade Finish Depth Depth Diameter Cost
(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 8006 5.5 17.00 E-80 LT&C 8006 8006 4.767 264198
Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design
(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 4159 6290 1.512 4159 7740 1.86 115.5 320 2.77 J
Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas & Mining FAX: 801-359-3940 Salt Lake City, Utah
Remarks:Collapse is based on a vertical depth of 8006 ft, a mud weight of 10 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.
Burst strength is not adjusted for tension.
Engineering responsibility for use of thisdesign wi/Ibe thatof the
RECEIVED: January 27, 2014
ON-SITE PREDRILL EVALUATIONUtah Division of Oil, Gas and Mining
Operator CRESCENT POINT ENERGY U.S. CORP Well Name ULT 12-5-4-2EAPI Number 43047540820000 APD No 8 8 6 1 Field/Unit LELAND BENCHLocation: 1/4,1/4 NWSW Sec 5 T w 4.0S Rng 2.0E 2091 FSL 948 FWLGPS Coord (UTM) 602247 4446509 Surface Owner Golbert Maggs
ParticipantsTed Smith-DOGM, Bryan Foote, Mike Wock,Phillip Taufa-Cresent Point Energy, Don HamiltonStar Point Enterprises, Allen Smith-Landowner,Mark Hecksel-D.R.Griffin and Associates
Regional/Local Setting & TopographyThe general area is on Leland Bench, which is located about 8 miles southeast of Ft. Duchesne,Uintah County, Utah. Broad flats with low growing desert shrub type vegetation characterizeLeland Bench. A few rolling hills and slopes leading to higher flats occur. No springs, seeps orflowing streams are known to occur in the area. The Duchesne River is approximately 2 milesto the north. All lands in the immediate are privately owned. Ute Tribal lands lie to thenor theas t and southwest .
Access to the proposed well site is by State Of Utah and Uintah County roads and existing orproposed oilfield development roads. Distance from Roosevelt , Utah is approximately 18 miles.Approximately 0.14 miles of low standard new road will be constructed to reach the locationusing a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flat with a slight slope to the south. A rise orhigher level occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, Utah LandTrust owns the surface. Mr.Maggs was contacted by telephone and invited to attend thepre-site visit . He said he would not attend. Mr. Allen Smith is representing Mr. Maggs and hadno issues with this location. A surface use agreement has been completed. The locationappears to be a good site for constructing a pad, dril l ing and operating a well .
Surface Use PlanCurrent Surface UseGrazingWildlfe Habitat
New RoadMiles
Well Pad Src Const Material Surface Formation
0 .14 Width 320 Length 4 0 0 Onsi te ALLU
Ancillary Facilities N
Waste Management Plan Adequate? Y
Environmental ParametersAffected Floodplains and/or Wetlands N
Flora / Fauna
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
ON-SITE PREDRILL EVALUATIONUtah Division of Oil, Gas and Mining
Operator CRESCENT POINT ENERGY U.S. CORPWell Name ULT 12-5-4-2E
APINumber 43047540820000 APDNo 8861 Field/Unit LELANDBENCHLocation: 1/4,1/4 NWSW Sec 5 Tw 4.0S Rng 2.0E 2091 FSL 948 FWLGPS Coord (UTM) 602247 4446509 Surface Owner Golbert Maggs
ParticipantsTed Smith-DOGM, Bryan Foote, Mike Wock,Phillip Taufa-Cresent Point Energy, Don HamiltonStar Point Enterprises, Allen Smith-Landowner,Mark Hecksel-D.R.Griffin and Associates
Regional/Local Setting & TopographyThe general area is on Leland Bench, which is located about 8 miles southeast of Ft. Duchesne,Uintah County, Utah. Broad flats with low growing desert shrub type vegetation characterizeLeland Bench. A few rolling hills and slopes leading to higher flats occur. No springs, seeps orflowing streams are known to occur in the area. The Duchesne River is approximately 2 milesto the north. All lands in the immediate are privately owned. Ute Tribal lands lie to thenortheast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existing orproposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18 miles.Approximately 0.14 miles of low standard new road will be constructed to reach the locationusing a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flat with a slight slope to the south. A rise orhigher level occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, Utah LandTrust owns the surface. Mr.Maggs was contacted by telephone and invited to attend thepre-site visit. He said he would not attend. Mr. Allen Smith is representing Mr. Maggs and hadno issues with this location. A surface use agreement has been completed. The locationappears to be a good site for constructing a pad, drilling and operating a well.
Surface Use PlanCurrent Surface UseGrazingWildlfe Habitat
New Road Well Pad Src Const Material Surface FormationMiles0.14 Width 320 Length 400 Onsite ALLU
Ancillary Facilities N
Waste Management Plan Adequate? Y
Environmental ParametersAffected Floodplains and/or Wetlands N
Flora / Fauna
RECEIVED: January 27,
API Well Number: 43047540820000
ON-SITE PREDRILL EVALUATIONUtah Division of Oil, Gas and Mining
Operator CRESCENT POINT ENERGY U.S. CORPWell Name ULT 12-5-4-2E
APINumber 43047540820000 APDNo 8861 Field/Unit LELANDBENCHLocation: 1/4,1/4 NWSW Sec 5 Tw 4.0S Rng 2.0E 2091 FSL 948 FWLGPS Coord (UTM) 602247 4446509 Surface Owner Golbert Maggs
ParticipantsTed Smith-DOGM, Bryan Foote, Mike Wock,Phillip Taufa-Cresent Point Energy, Don HamiltonStar Point Enterprises, Allen Smith-Landowner,Mark Hecksel-D.R.Griffin and Associates
Regional/Local Setting & TopographyThe general area is on Leland Bench, which is located about 8 miles southeast of Ft. Duchesne,Uintah County, Utah. Broad flats with low growing desert shrub type vegetation characterizeLeland Bench. A few rolling hills and slopes leading to higher flats occur. No springs, seeps orflowing streams are known to occur in the area. The Duchesne River is approximately 2 milesto the north. All lands in the immediate are privately owned. Ute Tribal lands lie to thenortheast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existing orproposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18 miles.Approximately 0.14 miles of low standard new road will be constructed to reach the locationusing a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flat with a slight slope to the south. A rise orhigher level occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, Utah LandTrust owns the surface. Mr.Maggs was contacted by telephone and invited to attend thepre-site visit. He said he would not attend. Mr. Allen Smith is representing Mr. Maggs and hadno issues with this location. A surface use agreement has been completed. The locationappears to be a good site for constructing a pad, drilling and operating a well.
Surface Use PlanCurrent Surface UseGrazingWildlfe Habitat
New Road Well Pad Src Const Material Surface FormationMiles0.14 Width 320 Length 400 Onsite ALLU
Ancillary Facilities N
Waste Management Plan Adequate? Y
Environmental ParametersAffected Floodplains and/or Wetlands N
Flora / Fauna
RECEIVED: January 27,
API Well Number: 43047540820000
ON-SITE PREDRILL EVALUATIONUtah Division of Oil, Gas and Mining
Operator CRESCENT POINT ENERGY U.S. CORPWell Name ULT 12-5-4-2E
APINumber 43047540820000 APDNo 8861 Field/Unit LELANDBENCHLocation: 1/4,1/4 NWSW Sec 5 Tw 4.0S Rng 2.0E 2091 FSL 948 FWLGPS Coord (UTM) 602247 4446509 Surface Owner Golbert Maggs
ParticipantsTed Smith-DOGM, Bryan Foote, Mike Wock,Phillip Taufa-Cresent Point Energy, Don HamiltonStar Point Enterprises, Allen Smith-Landowner,Mark Hecksel-D.R.Griffin and Associates
Regional/Local Setting & TopographyThe general area is on Leland Bench, which is located about 8 miles southeast of Ft. Duchesne,Uintah County, Utah. Broad flats with low growing desert shrub type vegetation characterizeLeland Bench. A few rolling hills and slopes leading to higher flats occur. No springs, seeps orflowing streams are known to occur in the area. The Duchesne River is approximately 2 milesto the north. All lands in the immediate are privately owned. Ute Tribal lands lie to thenortheast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existing orproposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18 miles.Approximately 0.14 miles of low standard new road will be constructed to reach the locationusing a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flat with a slight slope to the south. A rise orhigher level occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, Utah LandTrust owns the surface. Mr.Maggs was contacted by telephone and invited to attend thepre-site visit. He said he would not attend. Mr. Allen Smith is representing Mr. Maggs and hadno issues with this location. A surface use agreement has been completed. The locationappears to be a good site for constructing a pad, drilling and operating a well.
Surface Use PlanCurrent Surface UseGrazingWildlfe Habitat
New Road Well Pad Src Const Material Surface FormationMiles0.14 Width 320 Length 400 Onsite ALLU
Ancillary Facilities N
Waste Management Plan Adequate? Y
Environmental ParametersAffected Floodplains and/or Wetlands N
Flora / Fauna
RECEIVED: January 27,
API Well Number: 43047540820000
ON-SITE PREDRILL EVALUATIONUtah Division of Oil, Gas and Mining
Operator CRESCENT POINT ENERGY U.S. CORPWell Name ULT 12-5-4-2E
APINumber 43047540820000 APDNo 8861 Field/Unit LELANDBENCHLocation: 1/4,1/4 NWSW Sec 5 Tw 4.0S Rng 2.0E 2091 FSL 948 FWLGPS Coord (UTM) 602247 4446509 Surface Owner Golbert Maggs
ParticipantsTed Smith-DOGM, Bryan Foote, Mike Wock,Phillip Taufa-Cresent Point Energy, Don HamiltonStar Point Enterprises, Allen Smith-Landowner,Mark Hecksel-D.R.Griffin and Associates
Regional/Local Setting & TopographyThe general area is on Leland Bench, which is located about 8 miles southeast of Ft. Duchesne,Uintah County, Utah. Broad flats with low growing desert shrub type vegetation characterizeLeland Bench. A few rolling hills and slopes leading to higher flats occur. No springs, seeps orflowing streams are known to occur in the area. The Duchesne River is approximately 2 milesto the north. All lands in the immediate are privately owned. Ute Tribal lands lie to thenortheast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existing orproposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18 miles.Approximately 0.14 miles of low standard new road will be constructed to reach the locationusing a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flat with a slight slope to the south. A rise orhigher level occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, Utah LandTrust owns the surface. Mr.Maggs was contacted by telephone and invited to attend thepre-site visit. He said he would not attend. Mr. Allen Smith is representing Mr. Maggs and hadno issues with this location. A surface use agreement has been completed. The locationappears to be a good site for constructing a pad, drilling and operating a well.
Surface Use PlanCurrent Surface UseGrazingWildlfe Habitat
New Road Well Pad Src Const Material Surface FormationMiles0.14 Width 320 Length 400 Onsite ALLU
Ancillary Facilities N
Waste Management Plan Adequate? Y
Environmental ParametersAffected Floodplains and/or Wetlands N
Flora / Fauna
RECEIVED: January 27,
RECEIVED: January 27, 2014
Vegetation is a fair desert shrub-forb type. Main plants are horse-brush, Gardnersal t-brush, broom snakeweed, bud sagebrush, black sagebrush, cheatgrass, curlymesquite grass, prickly pear, globe mallow, squirrel tail and annual forbs.
Because of the lack of water and cover the area is not rich in fauna. Antelope, coyotes,prair ie dogs and small mammals and rodents occur . Some shrub dependent birds mayoccur but were not observed. Historically but not currently sheep grazed the area. Cattlenow graze the area
Soil Type and CharacteristicsSoils are a deep sandy loam with little rock.
Erosion Issues N
Sedimentation Issues N
Site Stability Issues N
Drainage Diverson Required? N
Berm Required? N
Erosion Sedimentation Control Required? N
Paleo Survey Run? N Paleo Potental Observed? N Cultural Survey Run? N CulturalResources? N
Reserve Pit
Site-Specific Factors Site Ranking
Distance to Groundwater (feet) > 2 0 0 0Distance to Surface Water (feet) > 1 0 0 0 0Dist. Nearest Municipal Well (ft) > 5 2 8 0 0
Distance to Other Wells (feet) > 1 3 2 0 0Native Soil Type Mod permeabili ty 1 0
Fluid Type Fresh Water 5Drill Cuttings Normal Rock 0
Annual Precipitation (inches) 0Affected Populations
Presence Nearby Utility Conduits Unknown 1 0
Final Score 2 5 3 Sensitivity Level
Characteristics / RequirementsOne 140’ x 100’ x 12’ and one 100' x 60' x 12' deep reserve pits are planned in a cut on thesouthwest corner of the location. A liner with a minimum thickness of 16-mils isrequired. A sub-liner may not be needed because of the lack of rock in the area. Operatorsays they will lay a subliner. Flare pit will be constructed 15' x 30 ' x 5 '
Closed Loop Mud Required? N Liner Required? Y Liner Thickness 16 Pit UnderlaymentRequired? N
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Vegetation is a fair desert shrub-forb type. Main plants are horse-brush, Gardnersalt-brush, broom snakeweed, bud sagebrush, black sagebrush, cheatgrass, curlymesquite grass, prickly pear, globe mallow, squirrel tail and annual forbs.
Because of the lack of water and cover the area is not rich in fauna. Antelope, coyotes,prairie dogs and small mammals and rodents occur. Some shrub dependent birds mayoccur but were not observed. Historically but not currently sheep grazed the area. Cattlenow graze the area
Soil Type and CharacteristicsSoils are a deep sandy loam with little rock.
Erosion Issues N
Sedimentation Issues N
Site Stability Issues N
Drainage Diverson Required? N
Berm Required? N
Erosion Sedimentation Control Required? N
Paleo Survey Run? N Paleo Potental Observed? N Cultural Survey Run? N CulturalResources? N
Reserve Pit
Site-Specific Factors Site Ranking
Distance to Groundwater (feet) >200 0Distance to Surface Water (feet) >1000 0Dist. Nearest Municipal Well (ft) > 5 2 8 0 0
Distance to Other Wells (feet) >1320 0Native Soil Type Mod permeability 10
Fluid Type Fresh Water 5Drill Cuttings Normal Rock 0
Annual Precipitation (inches) 0Affected Populations
Presence Nearby Utility Conduits Unknown 10Final Score 2 5 3 Sensitivity Level
Characteristics / RequirementsOne 140' x 100' x 12' and one 100' x 60' x 12' deep reserve pits are planned in a cut on thesouthwest corner of the location. A liner with a minimum thickness of 16-mils isrequired. A sub-liner may not be needed because of the lack of rock in the area. Operatorsays they will lay a subliner. Flare pit will be constructed 15' x 30 ' x 5 '
Closed Loop Mud Required? N Liner Required? Y Liner Thickness 16 Pit UnderlaymentRequired? N
RECEIVED: January 27,
API Well Number: 43047540820000
Vegetation is a fair desert shrub-forb type. Main plants are horse-brush, Gardnersalt-brush, broom snakeweed, bud sagebrush, black sagebrush, cheatgrass, curlymesquite grass, prickly pear, globe mallow, squirrel tail and annual forbs.
Because of the lack of water and cover the area is not rich in fauna. Antelope, coyotes,prairie dogs and small mammals and rodents occur. Some shrub dependent birds mayoccur but were not observed. Historically but not currently sheep grazed the area. Cattlenow graze the area
Soil Type and CharacteristicsSoils are a deep sandy loam with little rock.
Erosion Issues N
Sedimentation Issues N
Site Stability Issues N
Drainage Diverson Required? N
Berm Required? N
Erosion Sedimentation Control Required? N
Paleo Survey Run? N Paleo Potental Observed? N Cultural Survey Run? N CulturalResources? N
Reserve Pit
Site-Specific Factors Site Ranking
Distance to Groundwater (feet) >200 0Distance to Surface Water (feet) >1000 0Dist. Nearest Municipal Well (ft) > 5 2 8 0 0
Distance to Other Wells (feet) >1320 0Native Soil Type Mod permeability 10
Fluid Type Fresh Water 5Drill Cuttings Normal Rock 0
Annual Precipitation (inches) 0Affected Populations
Presence Nearby Utility Conduits Unknown 10Final Score 2 5 3 Sensitivity Level
Characteristics / RequirementsOne 140' x 100' x 12' and one 100' x 60' x 12' deep reserve pits are planned in a cut on thesouthwest corner of the location. A liner with a minimum thickness of 16-mils isrequired. A sub-liner may not be needed because of the lack of rock in the area. Operatorsays they will lay a subliner. Flare pit will be constructed 15' x 30 ' x 5 '
Closed Loop Mud Required? N Liner Required? Y Liner Thickness 16 Pit UnderlaymentRequired? N
RECEIVED: January 27,
API Well Number: 43047540820000
Vegetation is a fair desert shrub-forb type. Main plants are horse-brush, Gardnersalt-brush, broom snakeweed, bud sagebrush, black sagebrush, cheatgrass, curlymesquite grass, prickly pear, globe mallow, squirrel tail and annual forbs.
Because of the lack of water and cover the area is not rich in fauna. Antelope, coyotes,prairie dogs and small mammals and rodents occur. Some shrub dependent birds mayoccur but were not observed. Historically but not currently sheep grazed the area. Cattlenow graze the area
Soil Type and CharacteristicsSoils are a deep sandy loam with little rock.
Erosion Issues N
Sedimentation Issues N
Site Stability Issues N
Drainage Diverson Required? N
Berm Required? N
Erosion Sedimentation Control Required? N
Paleo Survey Run? N Paleo Potental Observed? N Cultural Survey Run? N CulturalResources? N
Reserve Pit
Site-Specific Factors Site Ranking
Distance to Groundwater (feet) >200 0Distance to Surface Water (feet) >1000 0Dist. Nearest Municipal Well (ft) > 5 2 8 0 0
Distance to Other Wells (feet) >1320 0Native Soil Type Mod permeability 10
Fluid Type Fresh Water 5Drill Cuttings Normal Rock 0
Annual Precipitation (inches) 0Affected Populations
Presence Nearby Utility Conduits Unknown 10Final Score 2 5 3 Sensitivity Level
Characteristics / RequirementsOne 140' x 100' x 12' and one 100' x 60' x 12' deep reserve pits are planned in a cut on thesouthwest corner of the location. A liner with a minimum thickness of 16-mils isrequired. A sub-liner may not be needed because of the lack of rock in the area. Operatorsays they will lay a subliner. Flare pit will be constructed 15' x 30 ' x 5 '
Closed Loop Mud Required? N Liner Required? Y Liner Thickness 16 Pit UnderlaymentRequired? N
RECEIVED: January 27,
API Well Number: 43047540820000
Vegetation is a fair desert shrub-forb type. Main plants are horse-brush, Gardnersalt-brush, broom snakeweed, bud sagebrush, black sagebrush, cheatgrass, curlymesquite grass, prickly pear, globe mallow, squirrel tail and annual forbs.
Because of the lack of water and cover the area is not rich in fauna. Antelope, coyotes,prairie dogs and small mammals and rodents occur. Some shrub dependent birds mayoccur but were not observed. Historically but not currently sheep grazed the area. Cattlenow graze the area
Soil Type and CharacteristicsSoils are a deep sandy loam with little rock.
Erosion Issues N
Sedimentation Issues N
Site Stability Issues N
Drainage Diverson Required? N
Berm Required? N
Erosion Sedimentation Control Required? N
Paleo Survey Run? N Paleo Potental Observed? N Cultural Survey Run? N CulturalResources? N
Reserve Pit
Site-Specific Factors Site Ranking
Distance to Groundwater (feet) >200 0Distance to Surface Water (feet) >1000 0Dist. Nearest Municipal Well (ft) > 5 2 8 0 0
Distance to Other Wells (feet) >1320 0Native Soil Type Mod permeability 10
Fluid Type Fresh Water 5Drill Cuttings Normal Rock 0
Annual Precipitation (inches) 0Affected Populations
Presence Nearby Utility Conduits Unknown 10Final Score 2 5 3 Sensitivity Level
Characteristics / RequirementsOne 140' x 100' x 12' and one 100' x 60' x 12' deep reserve pits are planned in a cut on thesouthwest corner of the location. A liner with a minimum thickness of 16-mils isrequired. A sub-liner may not be needed because of the lack of rock in the area. Operatorsays they will lay a subliner. Flare pit will be constructed 15' x 30 ' x 5 '
Closed Loop Mud Required? N Liner Required? Y Liner Thickness 16 Pit UnderlaymentRequired? N
RECEIVED: January 27,
RECEIVED: January 27, 2014
Other Observations / CommentsGilbert Maggs, Utah Land Trust owns the surface. Mr.Maggs was contacted by telephone andinvited to attend the pre-site visit . He said he would not attend. Mr. Alen Smith representedhim and had no issues with this location.
Ted Smith 1 1 / 1 4 / 2 0 1 3Evaluator Date / Time
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Other Observations / CommentsGilbert Maggs, Utah Land Trust owns the surface. Mr.Maggs was contacted by telephone andinvited to attend the pre-site visit. He said he would not attend. Mr. Alen Smith representedhim and had no issues with this location.
Ted Smith 11/14/2013Evaluator Date / Time
RECEIVED: January 27,
API Well Number: 43047540820000
Other Observations / CommentsGilbert Maggs, Utah Land Trust owns the surface. Mr.Maggs was contacted by telephone andinvited to attend the pre-site visit. He said he would not attend. Mr. Alen Smith representedhim and had no issues with this location.
Ted Smith 11/14/2013Evaluator Date / Time
RECEIVED: January 27,
API Well Number: 43047540820000
Other Observations / CommentsGilbert Maggs, Utah Land Trust owns the surface. Mr.Maggs was contacted by telephone andinvited to attend the pre-site visit. He said he would not attend. Mr. Alen Smith representedhim and had no issues with this location.
Ted Smith 11/14/2013Evaluator Date / Time
RECEIVED: January 27,
API Well Number: 43047540820000
Other Observations / CommentsGilbert Maggs, Utah Land Trust owns the surface. Mr.Maggs was contacted by telephone andinvited to attend the pre-site visit. He said he would not attend. Mr. Alen Smith representedhim and had no issues with this location.
Ted Smith 11/14/2013Evaluator Date / Time
RECEIVED: January 27,
RECEIVED: January 27, 2014
Application for Permit to DrillStatement of Basis
Utah Division of Oil, Gas and Mining
APD No API WellNo Status Well Type Surf Owner CBM8 8 6 1 43047540820000 LOCKED OW P N oOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Golbert MaggsWell Name ULT 12-5-4-2E UnitField LELAND BENCH Type of Work DRILL
Location NWSW 5 4S 2E U 2091 FSL 948 FWL GPS Coord(UTM) 602249E 4446516N
Geologic Statement of BasisCrescent Point proposes to set 1,000' of surface casing at this location. The base of themoderately saline water at this location is estimated to be at a depth of 1,400 feet. A searchof Division of Water Rights records shows 1 water well within a 10,000 foot radius of thecenter of Section 5. It produces from a depth of 500 feet and is used for irrigation, stockwatering and domestic use. The surface formation at this si te is the Uinta Formation. TheUinta Formation is made up of interbedded shales and sandstones. The sandstones aremostly lenticular and discontinuous and should not be a significant source of useableground water . Cement for the production str ing should be brought up above the base of themoderately saline groundwater in order to isolate fresher waters uphole.
Brad HillAPD Evaluator
1 2 / 1 8 / 2 0 1 3Date / Time
Surface Statement of BasisThe general area is on Leland Bench, which is located about 8 miles southeast of Ft.Duchesne, Uintah County, Utah. Broad flats with low growing desert shrub type vegetationcharacterize Leland Bench. A few rolling hills and slopes leading to higher flats occur. Nosprings, seeps or flowing streams are known to occur in the area. The Duchesne River isapproximately 2 miles to the north. All lands in the immediate are privately owned. UteTribal lands l ie to the northeast and southwest .
Access to the proposed well site is by State Of Utah and Uintah County roads and existingor proposed oilfield development roads. Distance from Roosevelt , Utah is approximately 18miles. Approximately 0.14 miles of low standard new road will be constructed to reach thelocation using one a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flatwith a slope to the south. A rise or higherlevel occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, UtahLand Trust owns the surface. Mr.Maggs was contacted by telephone and invited to attendthe pre-site visit . He said he would not attend. Mr. Allen Smith attended in his place. Asurface use agreement has been completed. The location appears to be a good si te forconstructing a pad, drill ing and operating a well.
Ted SmithOnsite Evaluator
1 1 / 1 4 / 2 0 1 3Date / Time
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
I
Application for Permit to DrillStatement of Basis
Utah Division of Oil, Gas and MiningI
APD No API WellNo Status Well Type Surf Owner CBM8861 43047540820000 LOCKED OW P NoOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Golbert MaggsWell Name ULT 12-5-4-2E UnitField LELAND BENCH Type of Work DRILL
. NWSW 5 4S 2E U 2091 FSL 948 FWL GPS CoordLocation(UTM) 602249E 4446516N
Geologic Statement of BasisCrescent Point proposes to set 1,000' of surface casing at this location. The base of themoderately saline water at this location is estimated to be at a depth of 1,400 feet. A searchof Division of Water Rights records shows 1 water well within a 10,000 foot radius of thecenter of Section 5. It produces from a depth of 500 feet and is used for irrigation, stockwatering and domestic use. The surface formation at this site is the Uinta Formation. TheUinta Formation is made up of interbedded shales and sandstones. The sandstones aremostly lenticular and discontinuous and should not be a significant source of useableground water. Cement for the production string should be brought up above the base of themoderately saline groundwater in order to isolate fresher waters uphole.
Brad Hill 12/18/20 13APD Evaluator Date / Time
Surface Statement of BasisThe general area is on Leland Bench, which is located about 8 miles southeast of Ft.Duchesne, Uintah County, Utah. Broad flats with low growing desert shrub type vegetationcharacterize Leland Bench. A few rolling hills and slopes leading to higher flats occur. Nosprings, seeps or flowing streams are known to occur in the area. The Duchesne River isapproximately 2 miles to the north. All lands in the immediate are privately owned. UteTribal lands lie to the northeast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existingor proposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18miles. Approximately 0.14 miles of low standard new road will be constructed to reach thelocation using one a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flatwith a slope to the south. A rise or higherlevel occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, UtahLand Trust owns the surface. Mr.Maggs was contacted by telephone and invited to attendthe pre-site visit. He said he would not attend. Mr. Allen Smith attended in his place. Asurface use agreement has been completed. The location appears to be a good site forconstructing a pad, drilling and operating a well.
Ted Smith 11/14/20 13Onsite Evaluator Date / Time
RECEIVED: January 27,
API Well Number: 43047540820000
I
Application for Permit to DrillStatement of Basis
Utah Division of Oil, Gas and MiningI
APD No API WellNo Status Well Type Surf Owner CBM8861 43047540820000 LOCKED OW P NoOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Golbert MaggsWell Name ULT 12-5-4-2E UnitField LELAND BENCH Type of Work DRILL
. NWSW 5 4S 2E U 2091 FSL 948 FWL GPS CoordLocation(UTM) 602249E 4446516N
Geologic Statement of BasisCrescent Point proposes to set 1,000' of surface casing at this location. The base of themoderately saline water at this location is estimated to be at a depth of 1,400 feet. A searchof Division of Water Rights records shows 1 water well within a 10,000 foot radius of thecenter of Section 5. It produces from a depth of 500 feet and is used for irrigation, stockwatering and domestic use. The surface formation at this site is the Uinta Formation. TheUinta Formation is made up of interbedded shales and sandstones. The sandstones aremostly lenticular and discontinuous and should not be a significant source of useableground water. Cement for the production string should be brought up above the base of themoderately saline groundwater in order to isolate fresher waters uphole.
Brad Hill 12/18/20 13APD Evaluator Date / Time
Surface Statement of BasisThe general area is on Leland Bench, which is located about 8 miles southeast of Ft.Duchesne, Uintah County, Utah. Broad flats with low growing desert shrub type vegetationcharacterize Leland Bench. A few rolling hills and slopes leading to higher flats occur. Nosprings, seeps or flowing streams are known to occur in the area. The Duchesne River isapproximately 2 miles to the north. All lands in the immediate are privately owned. UteTribal lands lie to the northeast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existingor proposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18miles. Approximately 0.14 miles of low standard new road will be constructed to reach thelocation using one a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flatwith a slope to the south. A rise or higherlevel occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, UtahLand Trust owns the surface. Mr.Maggs was contacted by telephone and invited to attendthe pre-site visit. He said he would not attend. Mr. Allen Smith attended in his place. Asurface use agreement has been completed. The location appears to be a good site forconstructing a pad, drilling and operating a well.
Ted Smith 11/14/20 13Onsite Evaluator Date / Time
RECEIVED: January 27,
API Well Number: 43047540820000
I
Application for Permit to DrillStatement of Basis
Utah Division of Oil, Gas and MiningI
APD No API WellNo Status Well Type Surf Owner CBM8861 43047540820000 LOCKED OW P NoOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Golbert MaggsWell Name ULT 12-5-4-2E UnitField LELAND BENCH Type of Work DRILL
. NWSW 5 4S 2E U 2091 FSL 948 FWL GPS CoordLocation(UTM) 602249E 4446516N
Geologic Statement of BasisCrescent Point proposes to set 1,000' of surface casing at this location. The base of themoderately saline water at this location is estimated to be at a depth of 1,400 feet. A searchof Division of Water Rights records shows 1 water well within a 10,000 foot radius of thecenter of Section 5. It produces from a depth of 500 feet and is used for irrigation, stockwatering and domestic use. The surface formation at this site is the Uinta Formation. TheUinta Formation is made up of interbedded shales and sandstones. The sandstones aremostly lenticular and discontinuous and should not be a significant source of useableground water. Cement for the production string should be brought up above the base of themoderately saline groundwater in order to isolate fresher waters uphole.
Brad Hill 12/18/20 13APD Evaluator Date / Time
Surface Statement of BasisThe general area is on Leland Bench, which is located about 8 miles southeast of Ft.Duchesne, Uintah County, Utah. Broad flats with low growing desert shrub type vegetationcharacterize Leland Bench. A few rolling hills and slopes leading to higher flats occur. Nosprings, seeps or flowing streams are known to occur in the area. The Duchesne River isapproximately 2 miles to the north. All lands in the immediate are privately owned. UteTribal lands lie to the northeast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existingor proposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18miles. Approximately 0.14 miles of low standard new road will be constructed to reach thelocation using one a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flatwith a slope to the south. A rise or higherlevel occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, UtahLand Trust owns the surface. Mr.Maggs was contacted by telephone and invited to attendthe pre-site visit. He said he would not attend. Mr. Allen Smith attended in his place. Asurface use agreement has been completed. The location appears to be a good site forconstructing a pad, drilling and operating a well.
Ted Smith 11/14/20 13Onsite Evaluator Date / Time
RECEIVED: January 27,
API Well Number: 43047540820000
I
Application for Permit to DrillStatement of Basis
Utah Division of Oil, Gas and MiningI
APD No API WellNo Status Well Type Surf Owner CBM8861 43047540820000 LOCKED OW P NoOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Golbert MaggsWell Name ULT 12-5-4-2E UnitField LELAND BENCH Type of Work DRILL
. NWSW 5 4S 2E U 2091 FSL 948 FWL GPS CoordLocation(UTM) 602249E 4446516N
Geologic Statement of BasisCrescent Point proposes to set 1,000' of surface casing at this location. The base of themoderately saline water at this location is estimated to be at a depth of 1,400 feet. A searchof Division of Water Rights records shows 1 water well within a 10,000 foot radius of thecenter of Section 5. It produces from a depth of 500 feet and is used for irrigation, stockwatering and domestic use. The surface formation at this site is the Uinta Formation. TheUinta Formation is made up of interbedded shales and sandstones. The sandstones aremostly lenticular and discontinuous and should not be a significant source of useableground water. Cement for the production string should be brought up above the base of themoderately saline groundwater in order to isolate fresher waters uphole.
Brad Hill 12/18/20 13APD Evaluator Date / Time
Surface Statement of BasisThe general area is on Leland Bench, which is located about 8 miles southeast of Ft.Duchesne, Uintah County, Utah. Broad flats with low growing desert shrub type vegetationcharacterize Leland Bench. A few rolling hills and slopes leading to higher flats occur. Nosprings, seeps or flowing streams are known to occur in the area. The Duchesne River isapproximately 2 miles to the north. All lands in the immediate are privately owned. UteTribal lands lie to the northeast and southwest.
Access to the proposed well site is by State Of Utah and Uintah County roads and existingor proposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18miles. Approximately 0.14 miles of low standard new road will be constructed to reach thelocation using one a culvert as needed at intersect with county road.
The proposed ULT 12-5-4-2E oil well is on a flatwith a slope to the south. A rise or higherlevel occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, UtahLand Trust owns the surface. Mr.Maggs was contacted by telephone and invited to attendthe pre-site visit. He said he would not attend. Mr. Allen Smith attended in his place. Asurface use agreement has been completed. The location appears to be a good site forconstructing a pad, drilling and operating a well.
Ted Smith 11/14/20 13Onsite Evaluator Date / Time
RECEIVED: January 27,
RECEIVED: January 27, 2014
Conditions of Approval / Application for Permit to DrillCategory ConditionPits A synthetic l iner with a minimum thickness of 16 mils shall be properly installed and maintained in
the reserve pit .Pits The reserve pit should be located on the south side of the location.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of dril l ing operations.
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
Conditions of Approval / Application for Permit to DrillCategory ConditionPits A synthetic liner with a minimum thickness of 16 mils shall be properly installed and maintained in
the reserve pit.Pits The reserve pit should be located on the south side of the location.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of drilling operations.
RECEIVED: January 27,
API Well Number: 43047540820000
Conditions of Approval / Application for Permit to DrillCategory ConditionPits A synthetic liner with a minimum thickness of 16 mils shall be properly installed and maintained in
the reserve pit.Pits The reserve pit should be located on the south side of the location.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of drilling operations.
RECEIVED: January 27,
API Well Number: 43047540820000
Conditions of Approval / Application for Permit to DrillCategory ConditionPits A synthetic liner with a minimum thickness of 16 mils shall be properly installed and maintained in
the reserve pit.Pits The reserve pit should be located on the south side of the location.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of drilling operations.
RECEIVED: January 27,
API Well Number: 43047540820000
Conditions of Approval / Application for Permit to DrillCategory ConditionPits A synthetic liner with a minimum thickness of 16 mils shall be properly installed and maintained in
the reserve pit.Pits The reserve pit should be located on the south side of the location.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of drilling operations.
RECEIVED: January 27,
RECEIVED: January 27, 2014
WORKSHEETAPPLICATION FOR PERMIT TO DRILL
APD RECEIVED: 10/25 /2013 API NO. ASSIGNED: 43047540820000
WELL NAME: ULT 12-5-4-2E
OPERATOR: CRESCENT POINT ENERGY U.S. CORP (N3935) PHONE NUMBER: 303 382-6787
CONTACT: Lauren MacMillan
PROPOSED LOCATION: NWSW 05 040S 020E Permit Tech Review:
SURFACE: 2091 FSL 0948 FWL Engineering Review:
BOTTOM: 2091 FSL 0948 FWL Geology Review:
COUNTY: UINTAH
LATITUDE: 40.16278 LONGITUDE: -109.79930
UTM SURF EASTINGS: 602249.00 NORTHINGS: 4446516.00
FIELD NAME: LELAND BENCH
LEASE TYPE: 4 - Fee
LEASE NUMBER: FEE PROPOSED PRODUCING FORMATION(S): WASATCH
SURFACE OWNER: 4 - Fee COALBED METHANE: NO
RECEIVED AND/OR REVIEWED: LOCATION AND SITING:
PLAT R649-2 -3 .
Bond: STATE/FEE - LPM9080271 Unit:
Potash R649-3-2. General
Oil Shale 190-5
Oil Shale 190-3 R649-3-3. Exception
Oil Shale 190-13 Drilling Unit
Water Permit: 437478 Board Cause No: R649-3-3
RDCC Review: Effective Date:
Fee Surface Agreement Siting:
Intent to Commingle R649-3-11. Directional Drill
Commingling Approved
Comments: Presite Completed
Stipulations: 1 - Exception Location - dmason 5 - Statement of Basis - bhill 12 - Cement Volume (3) - hmacdonald 23 - Spacing - dmason 25 - Surface Casing - hmacdonald
API Well Number: 43047540820000
CONFIDE
NTIAL
API Well Number: 43047540820000
WORKSHEETAPPLICATION FOR PERMIT TO DRILL
I
I
APD RECEIVED: 10/25/2013 API NO. ASSIGNED: 43047540820000
WELL NAME: ULT 12-5-4-2E
OPERATOR: CRESCENT POINT ENERGY U.S. CORP (N3935) PHONE NUMBER: 303 382-6787
CONTACT: Lauren MacMillan
PROPOSED LOCATION: NWSWO5 040S 020E Permit Tech Review:
SURFACE: 2091 FSL 0948 FWL Engineering Review:
BOTTOM: 2091 FSL 0948 FWL Geology Review:
COUNTY: UINTAH
LATITUDE: 40.16278 LONGITUDE: -109.79930
UTM SURF EASTINGS: 602249.00 NORTHINGS: 4446516.00
FIELD NAME: LELANDBENCH
LEASE TYPE: 4 - Fee
LEASE NUMBER: FEE PROPOSED PRODUCING FORMATION(S): WASATCH
SURFACE OWNER: 4 - Fee COALBED METHANE: NO
I
RECEIVED ANDIOR REVIEWED: LOCATION AND SITING:
PLAT R649-2-3.
Bond: STATE/FEE - LPM9080271 Unit:
Potash R649-3-2. General
Oil Shale 190-5
Oil Shale 190-3 R649-3-3. Exception
Oil Shale 190-13 Drilling Unit
Water Permit: 437478 Board Cause No: R649-3-3
RDCC Review: Effective Date:
Fee Surface Agreement Siting:
Intent to Commingle R649-3-11. Directional Drill
Commingling Approved
I
Comments: Presite Completed
Stipulations: 1 - Exception Location - dmason5 - Statement of Basis - bhill12 - Cement Volume (3) - hmacdonald23 - Spacing - dmason25 - Surface Casing - hmacdonald
RECEIVED: January 27,
API Well Number: 43047540820000
WORKSHEETAPPLICATION FOR PERMIT TO DRILL
I
I
APD RECEIVED: 10/25/2013 API NO. ASSIGNED: 43047540820000
WELL NAME: ULT 12-5-4-2E
OPERATOR: CRESCENT POINT ENERGY U.S. CORP (N3935) PHONE NUMBER: 303 382-6787
CONTACT: Lauren MacMillan
PROPOSED LOCATION: NWSWO5 040S 020E Permit Tech Review:
SURFACE: 2091 FSL 0948 FWL Engineering Review:
BOTTOM: 2091 FSL 0948 FWL Geology Review:
COUNTY: UINTAH
LATITUDE: 40.16278 LONGITUDE: -109.79930
UTM SURF EASTINGS: 602249.00 NORTHINGS: 4446516.00
FIELD NAME: LELANDBENCH
LEASE TYPE: 4 - Fee
LEASE NUMBER: FEE PROPOSED PRODUCING FORMATION(S): WASATCH
SURFACE OWNER: 4 - Fee COALBED METHANE: NO
I
RECEIVED ANDIOR REVIEWED: LOCATION AND SITING:
PLAT R649-2-3.
Bond: STATE/FEE - LPM9080271 Unit:
Potash R649-3-2. General
Oil Shale 190-5
Oil Shale 190-3 R649-3-3. Exception
Oil Shale 190-13 Drilling Unit
Water Permit: 437478 Board Cause No: R649-3-3
RDCC Review: Effective Date:
Fee Surface Agreement Siting:
Intent to Commingle R649-3-11. Directional Drill
Commingling Approved
I
Comments: Presite Completed
Stipulations: 1 - Exception Location - dmason5 - Statement of Basis - bhill12 - Cement Volume (3) - hmacdonald23 - Spacing - dmason25 - Surface Casing - hmacdonald
RECEIVED: January 27,
API Well Number: 43047540820000
WORKSHEETAPPLICATION FOR PERMIT TO DRILL
I
I
APD RECEIVED: 10/25/2013 API NO. ASSIGNED: 43047540820000
WELL NAME: ULT 12-5-4-2E
OPERATOR: CRESCENT POINT ENERGY U.S. CORP (N3935) PHONE NUMBER: 303 382-6787
CONTACT: Lauren MacMillan
PROPOSED LOCATION: NWSWO5 040S 020E Permit Tech Review:
SURFACE: 2091 FSL 0948 FWL Engineering Review:
BOTTOM: 2091 FSL 0948 FWL Geology Review:
COUNTY: UINTAH
LATITUDE: 40.16278 LONGITUDE: -109.79930
UTM SURF EASTINGS: 602249.00 NORTHINGS: 4446516.00
FIELD NAME: LELANDBENCH
LEASE TYPE: 4 - Fee
LEASE NUMBER: FEE PROPOSED PRODUCING FORMATION(S): WASATCH
SURFACE OWNER: 4 - Fee COALBED METHANE: NO
I
RECEIVED ANDIOR REVIEWED: LOCATION AND SITING:
PLAT R649-2-3.
Bond: STATE/FEE - LPM9080271 Unit:
Potash R649-3-2. General
Oil Shale 190-5
Oil Shale 190-3 R649-3-3. Exception
Oil Shale 190-13 Drilling Unit
Water Permit: 437478 Board Cause No: R649-3-3
RDCC Review: Effective Date:
Fee Surface Agreement Siting:
Intent to Commingle R649-3-11. Directional Drill
Commingling Approved
I
Comments: Presite Completed
Stipulations: 1 - Exception Location - dmason5 - Statement of Basis - bhill12 - Cement Volume (3) - hmacdonald23 - Spacing - dmason25 - Surface Casing - hmacdonald
RECEIVED: January 27,
API Well Number: 43047540820000
WORKSHEETAPPLICATION FOR PERMIT TO DRILL
I
I
APD RECEIVED: 10/25/2013 API NO. ASSIGNED: 43047540820000
WELL NAME: ULT 12-5-4-2E
OPERATOR: CRESCENT POINT ENERGY U.S. CORP (N3935) PHONE NUMBER: 303 382-6787
CONTACT: Lauren MacMillan
PROPOSED LOCATION: NWSWO5 040S 020E Permit Tech Review:
SURFACE: 2091 FSL 0948 FWL Engineering Review:
BOTTOM: 2091 FSL 0948 FWL Geology Review:
COUNTY: UINTAH
LATITUDE: 40.16278 LONGITUDE: -109.79930
UTM SURF EASTINGS: 602249.00 NORTHINGS: 4446516.00
FIELD NAME: LELANDBENCH
LEASE TYPE: 4 - Fee
LEASE NUMBER: FEE PROPOSED PRODUCING FORMATION(S): WASATCH
SURFACE OWNER: 4 - Fee COALBED METHANE: NO
I
RECEIVED ANDIOR REVIEWED: LOCATION AND SITING:
PLAT R649-2-3.
Bond: STATE/FEE - LPM9080271 Unit:
Potash R649-3-2. General
Oil Shale 190-5
Oil Shale 190-3 R649-3-3. Exception
Oil Shale 190-13 Drilling Unit
Water Permit: 437478 Board Cause No: R649-3-3
RDCC Review: Effective Date:
Fee Surface Agreement Siting:
Intent to Commingle R649-3-11. Directional Drill
Commingling Approved
I
Comments: Presite Completed
Stipulations: 1 - Exception Location - dmason5 - Statement of Basis - bhill12 - Cement Volume (3) - hmacdonald23 - Spacing - dmason25 - Surface Casing - hmacdonald
RECEIVED: January 27,
Permit To Drill******************Well Name: ULT 12-5-4-2E
API Well Number: 43047540820000Lease Number: FEESurface Owner: FEE (PRIVATE) Approval Date: 1 / 2 7 / 2 0 1 4
Issued to:CRESCENT POINT ENERGY U.S. CORP, 555 17th Street, Suite 750, Denver, CO 80202
Authority:Pursuant to Utah Code Ann. 40-6-1 et seq. , and Utah Administrat ive CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-3. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.
Duration:This approval shall expire one year from the above date unless substantial andcontinuous operat ion is underway, or a request for extension is made prior to theexpirat ion date
Exception Location:Appropriate information has been submitted to DOGM and administrat ive approvalof the requested exception location is hereby granted.
General:Compliance with the requirements of Utah Admin. R. 649-1 et seq., the Oil and GasConservation General Rules, and the applicable terms and provisions of theapproved Application for permit to dril l .
Conditions of Approval:This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil , Gas andMining (the “Board”). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of i ts analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drill ing and spacing units in conformance with such analysis by fil inga Request for Agency Action with the Board.
State of Utaha DEPARTMENT OF NATURAL RESOURCES
-
.,5., MICHAEL R. STYLER
GARY R HERBERT E wcunw Drector
Gowrnor Division of Oil, Gas and MiningSPEINCERJ. COX JOHN R. HAZAL2euternal Gowtror DWslanDirector
Permit To Drillkkkkkkkkkkkkkkkkkk
Well Name: ULT 12-5-4-2EAPI Well Number: 43047540820000
Lease Number: FEESurface Owner: FEE (PRIVATE)Approval Date: 1/27/20 14
Issued to:CRESCENT POINT ENERGY U.S. CORP, 555 17th Street, Suite 750, Denver, CO 80202
Authority:Pursuant to Utah Code Ann. 40-6-1 et seq., and Utah Administrative CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-3. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.
Duration:This approval shall expire one year from the above date unless substantial andcontinuous operation is underway, or a request for extension is made prior to theexpiration date
Exception Location:Appropriate information has been submitted to DOGM and administrative approvalof the requested exception location is hereby granted.
General:Compliance with the requirements of Utah Admin. R. 649-1 et seq., the Oil and GasConservation General Rules, and the applicable terms and provisions of theapproved Application for permit to drill.
Conditions of Approval:This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil, Gas andMining (the "Board"). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of its analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drilling and spacing units in conformance with such analysis by filinga Request for Agency Action with the
State of Utaha DEPARTMENT OF NATURAL RESOURCES
-
.,5., MICHAEL R. STYLER
GARY R HERBERT E wcunw Drector
Gowrnor Division of Oil, Gas and MiningSPEINCERJ. COX JOHN R. HAZAL2euternal Gowtror DWslanDirector
Permit To Drillkkkkkkkkkkkkkkkkkk
Well Name: ULT 12-5-4-2EAPI Well Number: 43047540820000
Lease Number: FEESurface Owner: FEE (PRIVATE)Approval Date: 1/27/20 14
Issued to:CRESCENT POINT ENERGY U.S. CORP, 555 17th Street, Suite 750, Denver, CO 80202
Authority:Pursuant to Utah Code Ann. 40-6-1 et seq., and Utah Administrative CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-3. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.
Duration:This approval shall expire one year from the above date unless substantial andcontinuous operation is underway, or a request for extension is made prior to theexpiration date
Exception Location:Appropriate information has been submitted to DOGM and administrative approvalof the requested exception location is hereby granted.
General:Compliance with the requirements of Utah Admin. R. 649-1 et seq., the Oil and GasConservation General Rules, and the applicable terms and provisions of theapproved Application for permit to drill.
Conditions of Approval:This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil, Gas andMining (the "Board"). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of its analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drilling and spacing units in conformance with such analysis by filinga Request for Agency Action with the
State of Utaha DEPARTMENT OF NATURAL RESOURCES
-
.,5., MICHAEL R. STYLER
GARY R HERBERT E wcunw Drector
Gowrnor Division of Oil, Gas and MiningSPEINCERJ. COX JOHN R. HAZAL2euternal Gowtror DWslanDirector
Permit To Drillkkkkkkkkkkkkkkkkkk
Well Name: ULT 12-5-4-2EAPI Well Number: 43047540820000
Lease Number: FEESurface Owner: FEE (PRIVATE)Approval Date: 1/27/20 14
Issued to:CRESCENT POINT ENERGY U.S. CORP, 555 17th Street, Suite 750, Denver, CO 80202
Authority:Pursuant to Utah Code Ann. 40-6-1 et seq., and Utah Administrative CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-3. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.
Duration:This approval shall expire one year from the above date unless substantial andcontinuous operation is underway, or a request for extension is made prior to theexpiration date
Exception Location:Appropriate information has been submitted to DOGM and administrative approvalof the requested exception location is hereby granted.
General:Compliance with the requirements of Utah Admin. R. 649-1 et seq., the Oil and GasConservation General Rules, and the applicable terms and provisions of theapproved Application for permit to drill.
Conditions of Approval:This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil, Gas andMining (the "Board"). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of its analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drilling and spacing units in conformance with such analysis by filinga Request for Agency Action with the
State of Utaha DEPARTMENT OF NATURAL RESOURCES
-
.,5., MICHAEL R. STYLER
GARY R HERBERT E wcunw Drector
Gowrnor Division of Oil, Gas and MiningSPEINCERJ. COX JOHN R. HAZAL2euternal Gowtror DWslanDirector
Permit To Drillkkkkkkkkkkkkkkkkkk
Well Name: ULT 12-5-4-2EAPI Well Number: 43047540820000
Lease Number: FEESurface Owner: FEE (PRIVATE)Approval Date: 1/27/20 14
Issued to:CRESCENT POINT ENERGY U.S. CORP, 555 17th Street, Suite 750, Denver, CO 80202
Authority:Pursuant to Utah Code Ann. 40-6-1 et seq., and Utah Administrative CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-3. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.
Duration:This approval shall expire one year from the above date unless substantial andcontinuous operation is underway, or a request for extension is made prior to theexpiration date
Exception Location:Appropriate information has been submitted to DOGM and administrative approvalof the requested exception location is hereby granted.
General:Compliance with the requirements of Utah Admin. R. 649-1 et seq., the Oil and GasConservation General Rules, and the applicable terms and provisions of theapproved Application for permit to drill.
Conditions of Approval:This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil, Gas andMining (the "Board"). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of its analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drilling and spacing units in conformance with such analysis by filinga Request for Agency Action with the
Compliance with the Conditions of Approval/Application for Permit to Drilloutlined in the Statement of Basis (copy attached).
Cement volume for the 5 1/2" production str ing shall be determined from actualhole diameter in order to place cement from the pipe set t ing depth back to surfaceas indicated in the submitted dril l ing plan.
Surface casing shall be cemented to the surface.
Additional Approvals:The operator is required to obtain approval from the Division of Oil, Gas andmining before performing any of the following actions during the dril l ing of thiswell: • Any changes to the approved dri l l ing plan - contact Dustin Doucet • Significant plug back of the well - contact Dustin Doucet • Plug and abandonment of the well - contact Dustin Doucet
Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well: • Within 24 hours following the spudding of the well - contact Carol Daniels OR submit an electronic sundry notice (pre-registration required) via the Utah Oil &Gas website at ht tp:/ /oi lgas.ogm.utah.gov • 24 hours prior to test ing blowout prevention equipment - contact Dan Jarvis • 24 hours prior to cementing or test ing casing - contact Dan Jarvis • Within 24 hours of making any emergency changes to the approved dril l ingp r o g r a m - contact Dustin Doucet • 24 hours pr ior to commencing operat ions to plug and abandon the well -contact Dan Jarvis
Contact Information:The following are Division of Oil, Gas and Mining contacts and their telephonenumbers (please leave a voicemail message if the person is not available to take thecall): • Carol Daniels 801-538-5284 - off ice • Dust in Doucet 801-538-5281 - off ice 801-733-0983 - after office hours • Dan Jarvis 801-538-5338 - office 801-231-8956 - after office hours
Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not l imited to: • Entity Action Form (Form 6) - due within 5 days of spudding the well • Monthly Status Report (Form 9) - due by 5th day of the following calendarm o n t h • Requests to Change Plans (Form 9) - due prior to implementation
Compliance with the Conditions of Approval/Application for Permit to Drilloutlined in the Statement of Basis (copy attached).
Cement volume for the 5 1/2" production string shall be determined from actualhole diameter in order to place cement from the pipe setting depth back to surfaceas indicated in the submitted drilling plan.
Surface casing shall be cemented to the surface.
Additional Approvals:The operator is required to obtain approval from the Division of Oil, Gas andmining before performing any of the following actions during the drilling of thiswell:
• Any changes to the approved drilling plan - contact Dustin Doucet• Significant plug back of the well - contact Dustin Doucet• Plug and abandonment of the well - contact Dustin Doucet
Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well:
• Within 24 hours following the spudding of the well - contact Carol DanielsORsubmit an electronic sundry notice (pre-registration required) via the Utah Oil &
Gas websiteat http://oilgas.ogm.utah.gov
• 24 hours prior to testing blowout prevention equipment - contact Dan Jarvis• 24 hours prior to cementing or testing casing - contact Dan Jarvis• Within 24 hours of making any emergency changes to the approved drilling
program- contact Dustin Doucet
• 24 hours prior to commencing operations to plug and abandon the well -
contact Dan Jarvis
Contact Information:The following are Division of Oil, Gas and Mining contacts and their telephonenumbers (please leave a voicemail message if the person is not available to take thecall):
• Carol Daniels 801-538-5284 - office• Dustin Doucet 801-538-5281 - office
801-733-0983 - after office hours• Dan Jarvis 801-538-5338 - office
801-231-8956 - after office hours
Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not limited to:
• Entity Action Form (Form 6) - due within 5 days of spudding the well• Monthly Status Report (Form 9) - due by 5th day of the following calendar
month• Requests to Change Plans (Form 9) - due prior to
Compliance with the Conditions of Approval/Application for Permit to Drilloutlined in the Statement of Basis (copy attached).
Cement volume for the 5 1/2" production string shall be determined from actualhole diameter in order to place cement from the pipe setting depth back to surfaceas indicated in the submitted drilling plan.
Surface casing shall be cemented to the surface.
Additional Approvals:The operator is required to obtain approval from the Division of Oil, Gas andmining before performing any of the following actions during the drilling of thiswell:
• Any changes to the approved drilling plan - contact Dustin Doucet• Significant plug back of the well - contact Dustin Doucet• Plug and abandonment of the well - contact Dustin Doucet
Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well:
• Within 24 hours following the spudding of the well - contact Carol DanielsORsubmit an electronic sundry notice (pre-registration required) via the Utah Oil &
Gas websiteat http://oilgas.ogm.utah.gov
• 24 hours prior to testing blowout prevention equipment - contact Dan Jarvis• 24 hours prior to cementing or testing casing - contact Dan Jarvis• Within 24 hours of making any emergency changes to the approved drilling
program- contact Dustin Doucet
• 24 hours prior to commencing operations to plug and abandon the well -
contact Dan Jarvis
Contact Information:The following are Division of Oil, Gas and Mining contacts and their telephonenumbers (please leave a voicemail message if the person is not available to take thecall):
• Carol Daniels 801-538-5284 - office• Dustin Doucet 801-538-5281 - office
801-733-0983 - after office hours• Dan Jarvis 801-538-5338 - office
801-231-8956 - after office hours
Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not limited to:
• Entity Action Form (Form 6) - due within 5 days of spudding the well• Monthly Status Report (Form 9) - due by 5th day of the following calendar
month• Requests to Change Plans (Form 9) - due prior to
Compliance with the Conditions of Approval/Application for Permit to Drilloutlined in the Statement of Basis (copy attached).
Cement volume for the 5 1/2" production string shall be determined from actualhole diameter in order to place cement from the pipe setting depth back to surfaceas indicated in the submitted drilling plan.
Surface casing shall be cemented to the surface.
Additional Approvals:The operator is required to obtain approval from the Division of Oil, Gas andmining before performing any of the following actions during the drilling of thiswell:
• Any changes to the approved drilling plan - contact Dustin Doucet• Significant plug back of the well - contact Dustin Doucet• Plug and abandonment of the well - contact Dustin Doucet
Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well:
• Within 24 hours following the spudding of the well - contact Carol DanielsORsubmit an electronic sundry notice (pre-registration required) via the Utah Oil &
Gas websiteat http://oilgas.ogm.utah.gov
• 24 hours prior to testing blowout prevention equipment - contact Dan Jarvis• 24 hours prior to cementing or testing casing - contact Dan Jarvis• Within 24 hours of making any emergency changes to the approved drilling
program- contact Dustin Doucet
• 24 hours prior to commencing operations to plug and abandon the well -
contact Dan Jarvis
Contact Information:The following are Division of Oil, Gas and Mining contacts and their telephonenumbers (please leave a voicemail message if the person is not available to take thecall):
• Carol Daniels 801-538-5284 - office• Dustin Doucet 801-538-5281 - office
801-733-0983 - after office hours• Dan Jarvis 801-538-5338 - office
801-231-8956 - after office hours
Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not limited to:
• Entity Action Form (Form 6) - due within 5 days of spudding the well• Monthly Status Report (Form 9) - due by 5th day of the following calendar
month• Requests to Change Plans (Form 9) - due prior to
Compliance with the Conditions of Approval/Application for Permit to Drilloutlined in the Statement of Basis (copy attached).
Cement volume for the 5 1/2" production string shall be determined from actualhole diameter in order to place cement from the pipe setting depth back to surfaceas indicated in the submitted drilling plan.
Surface casing shall be cemented to the surface.
Additional Approvals:The operator is required to obtain approval from the Division of Oil, Gas andmining before performing any of the following actions during the drilling of thiswell:
• Any changes to the approved drilling plan - contact Dustin Doucet• Significant plug back of the well - contact Dustin Doucet• Plug and abandonment of the well - contact Dustin Doucet
Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well:
• Within 24 hours following the spudding of the well - contact Carol DanielsORsubmit an electronic sundry notice (pre-registration required) via the Utah Oil &
Gas websiteat http://oilgas.ogm.utah.gov
• 24 hours prior to testing blowout prevention equipment - contact Dan Jarvis• 24 hours prior to cementing or testing casing - contact Dan Jarvis• Within 24 hours of making any emergency changes to the approved drilling
program- contact Dustin Doucet
• 24 hours prior to commencing operations to plug and abandon the well -
contact Dan Jarvis
Contact Information:The following are Division of Oil, Gas and Mining contacts and their telephonenumbers (please leave a voicemail message if the person is not available to take thecall):
• Carol Daniels 801-538-5284 - office• Dustin Doucet 801-538-5281 - office
801-733-0983 - after office hours• Dan Jarvis 801-538-5338 - office
801-231-8956 - after office hours
Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not limited to:
• Entity Action Form (Form 6) - due within 5 days of spudding the well• Monthly Status Report (Form 9) - due by 5th day of the following calendar
month• Requests to Change Plans (Form 9) - due prior to
• Written Notice of Emergency Changes (Form 9) - due within 5 days • Notice of Operations Suspension or Resumption (Form 9) - due prior toimplementa t ion • Report of Water Encountered (Form 7) - due within 30 days after completion • Well Completion Report (Form 8) - due within 30 days after completion orplugging
Approved By:
For John RogersAssociate Director, Oil & Gas
• Written Notice of Emergency Changes (Form 9) - due within 5 days• Notice of Operations Suspension or Resumption (Form 9) - due prior to
implementation• Report of Water Encountered (Form 7) - due within 30 days after completion• Well Completion Report (Form 8) - due within 30 days after completion or
plugging
Approved By:
For John RogersAssociate Director, Oil &
• Written Notice of Emergency Changes (Form 9) - due within 5 days• Notice of Operations Suspension or Resumption (Form 9) - due prior to
implementation• Report of Water Encountered (Form 7) - due within 30 days after completion• Well Completion Report (Form 8) - due within 30 days after completion or
plugging
Approved By:
For John RogersAssociate Director, Oil &
• Written Notice of Emergency Changes (Form 9) - due within 5 days• Notice of Operations Suspension or Resumption (Form 9) - due prior to
implementation• Report of Water Encountered (Form 7) - due within 30 days after completion• Well Completion Report (Form 8) - due within 30 days after completion or
plugging
Approved By:
For John RogersAssociate Director, Oil &
• Written Notice of Emergency Changes (Form 9) - due within 5 days• Notice of Operations Suspension or Resumption (Form 9) - due prior to
implementation• Report of Water Encountered (Form 7) - due within 30 days after completion• Well Completion Report (Form 8) - due within 30 days after completion or
plugging
Approved By:
For John RogersAssociate Director, Oil &
RECEIVED: Dec. 18, 2014
STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES
DIVISION OF OIL, GAS, AND MINING
FORM 9
5.LEASE DESIGNATION AND SERIAL NUMBER: FEE
SUNDRY NOTICES AND REPORTS ON WELLS
Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATIONFOR PERMIT TO DRILL form for such proposals.
6. IF INDIAN, ALLOTTEE OR TRIBE NAME:
7.UNIT or CA AGREEMENT NAME:
1. TYPE OF WELL Oil Well
8. WELL NAME and NUMBER: ULT 12-5-4-2E
2. NAME OF OPERATOR: CRESCENT POINT ENERGY U.S. CORP
9. API NUMBER: 43047540820000
3. ADDRESS OF OPERATOR: PHONE NUMBER: 555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext
9. FIELD and POOL or WILDCAT: LELAND BENCH
4. LOCATION OF WELL FOOTAGES AT SURFACE: 2091 FSL 0948 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: NWSW Section: 05 Township: 04.0S Range: 02.0E Meridian: U
COUNTY: UINTAH
STATE: UTAH
11.
CHECK APPROPRIATE BOXES TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
NOTICE OF INTENTApproximate date work will start:
1 /27 /2014
SUBSEQUENT REPORTDate of Work Completion:
SPUD REPORTDate of Spud:
DRILLING REPORTReport Date:
ACIDIZE ALTER CASING CASING REPAIR
CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME
CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE
DEEPEN FRACTURE TREAT NEW CONSTRUCTION
OPERATOR CHANGE PLUG AND ABANDON PLUG BACK
PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION
REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON
TUBING REPAIR VENT OR FLARE WATER DISPOSAL
WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION
WILDCAT WELL DETERMINATION OTHER OTHER:
12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.
Crescent Point Energy U.S. Corp respectfully requests a one-yearextension of the state drilling permit for the ULT 12-5-4-2E.
NAME (PLEASE PRINT) PHONE NUMBER Kristen Johnson 303 308-6270
TITLE Regulatory Technician
SIGNATURE N/A
DATE 12/18/2014
December 18, 2014
Sundry Number: 59145 API Well Number: 43047540820000Sundry Number: 59145 API Well Number: 43047540820000
FORM 9STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING FEE
SUNDRY NOTICES AND REPORTS ON WELLS 6. IF INDIAN, ALLOTTEE OR TRIBE NAME:
Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION 7.UNITor CA AGREEMENT NAME:
FOR PERMIT TO DRILL form for such proposals.
1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well ULT 12-5-4-2E
2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047540820000
3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext LELANDBENCH
4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH
2091 FSL 0948 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:
QtrlQtr: NWSW Section: 05 Township: 04.0S Range: 02.0E Meridian: U UTAH
CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT
Approximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME
1/27/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE
SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:
OPERATOR CHANGE PLUG AND ABANDON PLUG BACK
PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT
Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON
TUBING REPAIR VENT OR FLARE WATER DISPOSAL
DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:
WILDCAT WELL DETERMINATION OTHER OTHER:
12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.
Crescent Point Energy U.S. Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the ULT 12-5-4-2E. GlaholinItietohSp12014
OFI, Gas and Mining
Date:
NAME (PLEASE PRINT) PHONE NUMBER TITLEKristen Johnson 303 308-6270 Regulatory Technician
SIGNATURE DATEN/A 12/18/2014
RECEIVED: Dec. 18,
Sundry Number: 59145 API Well Number: 43047540820000
FORM 9STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING FEE
SUNDRY NOTICES AND REPORTS ON WELLS 6. IF INDIAN, ALLOTTEE OR TRIBE NAME:
Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION 7.UNITor CA AGREEMENT NAME:
FOR PERMIT TO DRILL form for such proposals.
1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well ULT 12-5-4-2E
2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047540820000
3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext LELANDBENCH
4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH
2091 FSL 0948 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:
QtrlQtr: NWSW Section: 05 Township: 04.0S Range: 02.0E Meridian: U UTAH
CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT
Approximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME
1/27/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE
SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:
OPERATOR CHANGE PLUG AND ABANDON PLUG BACK
PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT
Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON
TUBING REPAIR VENT OR FLARE WATER DISPOSAL
DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:
WILDCAT WELL DETERMINATION OTHER OTHER:
12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.
Crescent Point Energy U.S. Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the ULT 12-5-4-2E. GlaholinItietohSp12014
OFI, Gas and Mining
Date:
NAME (PLEASE PRINT) PHONE NUMBER TITLEKristen Johnson 303 308-6270 Regulatory Technician
SIGNATURE DATEN/A 12/18/2014
RECEIVED: Dec. 18,
Sundry Number: 59145 API Well Number: 43047540820000
FORM 9STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING FEE
SUNDRY NOTICES AND REPORTS ON WELLS 6. IF INDIAN, ALLOTTEE OR TRIBE NAME:
Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION 7.UNITor CA AGREEMENT NAME:
FOR PERMIT TO DRILL form for such proposals.
1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well ULT 12-5-4-2E
2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047540820000
3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext LELANDBENCH
4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH
2091 FSL 0948 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:
QtrlQtr: NWSW Section: 05 Township: 04.0S Range: 02.0E Meridian: U UTAH
CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT
Approximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME
1/27/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE
SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:
OPERATOR CHANGE PLUG AND ABANDON PLUG BACK
PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT
Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON
TUBING REPAIR VENT OR FLARE WATER DISPOSAL
DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:
WILDCAT WELL DETERMINATION OTHER OTHER:
12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.
Crescent Point Energy U.S. Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the ULT 12-5-4-2E. GlaholinItietohSp12014
OFI, Gas and Mining
Date:
NAME (PLEASE PRINT) PHONE NUMBER TITLEKristen Johnson 303 308-6270 Regulatory Technician
SIGNATURE DATEN/A 12/18/2014
RECEIVED: Dec. 18,
RECEIVED: Dec. 18, 2014
The Utah Division of Oil, Gas, and Mining
- State of Utah- Department of Natural Resources
Electronic Permitting System - Sundry Notices
Request for Permit Extension Validation Well Number 43047540820000
API: 43047540820000Well Name: ULT 12-5-4-2E
Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP
Date Original Permit Issued: 1 /27 /2014
The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.
If located on private land, has the ownership changed, if so, has the surface agreement been updated? Yes No
Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? Yes No
Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? Yes No
Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? Yes No
Has the approved source of water for drilling changed? Yes No
Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No
Is bonding still in place, which covers this proposed well? Yes No
Signature: Kristen Johnson Date: 12/18 /2014
Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP
Sundry Number: 59145 API Well Number: 43047540820000Sundry Number: 59145 API Well Number: 43047540820000
UTAH
DNR The Utah Division of Oil, Gas, and Mining'
- State of Utah- Department of Natural Resources
Electronic Permitting System - Sundry NoticesOTI. EMI Pr N1NTrie
Request for Permit Extension Validation Well Number 43047540820000
API: 43047540820000Well Name: ULT 12-5-4-2E
Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP
Date Original Permit Issued: 1/27/2014
The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.
* If located on private land, has the ownership changed, if so, has the surface agreement been updated? OYes No
• Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? O Yes No
• Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? (_) Yes No
• Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? O Yes i No
· Has the approved source of water for drilling changed? O Yes No
• Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No
' Is bonding still in place, which covers this proposed well? Yes No
Signature: Kristen Johnson Date: 12/18/2014Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP
RECEIVED: Dec. 18,
Sundry Number: 59145 API Well Number: 43047540820000
UTAH
DNR The Utah Division of Oil, Gas, and Mining'
- State of Utah- Department of Natural Resources
Electronic Permitting System - Sundry NoticesOTI. EMI Pr N1NTrie
Request for Permit Extension Validation Well Number 43047540820000
API: 43047540820000Well Name: ULT 12-5-4-2E
Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP
Date Original Permit Issued: 1/27/2014
The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.
* If located on private land, has the ownership changed, if so, has the surface agreement been updated? OYes No
• Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? O Yes No
• Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? (_) Yes No
• Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? O Yes i No
· Has the approved source of water for drilling changed? O Yes No
• Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No
' Is bonding still in place, which covers this proposed well? Yes No
Signature: Kristen Johnson Date: 12/18/2014Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP
RECEIVED: Dec. 18,
Sundry Number: 59145 API Well Number: 43047540820000
UTAH
DNR The Utah Division of Oil, Gas, and Mining'
- State of Utah- Department of Natural Resources
Electronic Permitting System - Sundry NoticesOTI. EMI Pr N1NTrie
Request for Permit Extension Validation Well Number 43047540820000
API: 43047540820000Well Name: ULT 12-5-4-2E
Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP
Date Original Permit Issued: 1/27/2014
The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.
* If located on private land, has the ownership changed, if so, has the surface agreement been updated? OYes No
• Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? O Yes No
• Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? (_) Yes No
• Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? O Yes i No
· Has the approved source of water for drilling changed? O Yes No
• Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No
' Is bonding still in place, which covers this proposed well? Yes No
Signature: Kristen Johnson Date: 12/18/2014Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP
RECEIVED: Dec. 18,
RECEIVED: Jan. 04, 2016
STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES
DIVISION OF OIL, GAS, AND MINING
FORM 9
5.LEASE DESIGNATION AND SERIAL NUMBER: FEE
SUNDRY NOTICES AND REPORTS ON WELLS
Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATIONFOR PERMIT TO DRILL form for such proposals.
6. IF INDIAN, ALLOTTEE OR TRIBE NAME:
7.UNIT or CA AGREEMENT NAME:
1. TYPE OF WELL Oil Well
8. WELL NAME and NUMBER: ULT 12-5-4-2E
2. NAME OF OPERATOR: CRESCENT POINT ENERGY U.S. CORP
9. API NUMBER: 43047540820000
3. ADDRESS OF OPERATOR: PHONE NUMBER: 555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext
9. FIELD and POOL or WILDCAT: LELAND BENCH
4. LOCATION OF WELL FOOTAGES AT SURFACE: 2091 FSL 0948 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: NWSW Section: 05 Township: 04.0S Range: 02.0E Meridian: U
COUNTY: UINTAH
STATE: UTAH
11.
CHECK APPROPRIATE BOXES TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
NOTICE OF INTENTApproximate date work will start:
1 /27 /2016
SUBSEQUENT REPORTDate of Work Completion:
SPUD REPORTDate of Spud:
DRILLING REPORTReport Date:
ACIDIZE ALTER CASING CASING REPAIR
CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME
CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE
DEEPEN FRACTURE TREAT NEW CONSTRUCTION
OPERATOR CHANGE PLUG AND ABANDON PLUG BACK
PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION
REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON
TUBING REPAIR VENT OR FLARE WATER DISPOSAL
WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION
WILDCAT WELL DETERMINATION OTHER OTHER:
12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.
Crescent Point Energy US Corp respectfully requests a one-yearextension of the state drilling permit for the referenced well.
NAME (PLEASE PRINT) PHONE NUMBER Kristen Johnson 303 308-6270
TITLE Regulatory Technician
SIGNATURE N/A
DATE 1 /4 /2016
January 05, 2016
Sundry Number: 68715 API Well Number: 43047540820000Sundry Number: 68715 API Well Number: 43047540820000
FORM 9STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING FEE
SUNDRY NOTICES AND REPORTS ON WELLS 6. IF INDIAN, ALLOTTEE OR TRIBE NAME:
Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION 7.UNITor CA AGREEMENT NAME:
FOR PERMIT TO DRILL form for such proposals.
1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well ULT 12-5-4-2E
2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047540820000
3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext LELANDBENCH
4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH
2091 FSL 0948 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:
QtrlQtr: NWSW Section: 05 Township: 04.0S Range: 02.0E Meridian: U UTAH
CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT
Approximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME
1/27/2016CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE
SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:
OPERATOR CHANGE PLUG AND ABANDON PLUG BACK
PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT
Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON
TUBING REPAIR VENT OR FLARE WATER DISPOSAL
DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:
WILDCAT WELL DETERMINATION OTHER OTHER:
12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.
Crescent Point Energy US Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the referenced well. UJIarkumyiBlia,n2OI16
OFI, Gas and Mining
Date:
NAME (PLEASE PRINT) PHONE NUMBER TITLEKristen Johnson 303 308-6270 Regulatory Technician
SIGNATURE DATEN/A 1/4/2016
RECEIVED: Jan. 04,
Sundry Number: 68715 API Well Number: 43047540820000
FORM 9STATE OF UTAH
DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING FEE
SUNDRY NOTICES AND REPORTS ON WELLS 6. IF INDIAN, ALLOTTEE OR TRIBE NAME:
Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION 7.UNITor CA AGREEMENT NAME:
FOR PERMIT TO DRILL form for such proposals.
1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well ULT 12-5-4-2E
2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047540820000
3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext LELANDBENCH
4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH
2091 FSL 0948 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:
QtrlQtr: NWSW Section: 05 Township: 04.0S Range: 02.0E Meridian: U UTAH
CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATA
TYPE OF SUBMISSION TYPE OF ACTION
ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT
Approximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME
1/27/2016CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE
SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:
OPERATOR CHANGE PLUG AND ABANDON PLUG BACK
PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT
Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON
TUBING REPAIR VENT OR FLARE WATER DISPOSAL
DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:
WILDCAT WELL DETERMINATION OTHER OTHER:
12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.
Crescent Point Energy US Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the referenced well. UJIarkumyiBlia,n2OI16
OFI, Gas and Mining
Date:
NAME (PLEASE PRINT) PHONE NUMBER TITLEKristen Johnson 303 308-6270 Regulatory Technician
SIGNATURE DATEN/A 1/4/2016
RECEIVED: Jan. 04,
RECEIVED: Jan. 04, 2016
The Utah Division of Oil, Gas, and Mining
- State of Utah- Department of Natural Resources
Electronic Permitting System - Sundry Notices
Request for Permit Extension Validation Well Number 43047540820000
API: 43047540820000Well Name: ULT 12-5-4-2E
Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP
Date Original Permit Issued: 1 /27 /2014
The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.
If located on private land, has the ownership changed, if so, has the surface agreement been updated? Yes No
Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? Yes No
Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? Yes No
Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? Yes No
Has the approved source of water for drilling changed? Yes No
Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No
Is bonding still in place, which covers this proposed well? Yes No
Signature: Kristen Johnson Date: 1 /4 /2016
Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP
Sundry Number: 68715 API Well Number: 43047540820000Sundry Number: 68715 API Well Number: 43047540820000
UTAH
DNR The Utah Division of Oil, Gas, and Mining'
- State of Utah- Department of Natural Resources
Electronic Permitting System - Sundry NoticesOTI. EMI Pr N1NTrie
Request for Permit Extension Validation Well Number 43047540820000
API: 43047540820000Well Name: ULT 12-5-4-2E
Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP
Date Original Permit Issued: 1/27/2014
The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.
* If located on private land, has the ownership changed, if so, has the surface agreement been updated? OYes No
• Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? O Yes No
• Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? (_) Yes No
• Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? O Yes i No
· Has the approved source of water for drilling changed? O Yes No
• Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No
' Is bonding still in place, which covers this proposed well? Yes No
Signature: Kristen Johnson Date: 1/4/2016Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP
RECEIVED: Jan. 04,
Sundry Number: 68715 API Well Number: 43047540820000
UTAH
DNR The Utah Division of Oil, Gas, and Mining'
- State of Utah- Department of Natural Resources
Electronic Permitting System - Sundry NoticesOTI. EMI Pr N1NTrie
Request for Permit Extension Validation Well Number 43047540820000
API: 43047540820000Well Name: ULT 12-5-4-2E
Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP
Date Original Permit Issued: 1/27/2014
The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.
* If located on private land, has the ownership changed, if so, has the surface agreement been updated? OYes No
• Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? O Yes No
• Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? (_) Yes No
• Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? O Yes i No
· Has the approved source of water for drilling changed? O Yes No
• Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No
' Is bonding still in place, which covers this proposed well? Yes No
Signature: Kristen Johnson Date: 1/4/2016Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP
RECEIVED: Jan. 04,
State of UtahDEPARTMENT OF NATURAL RESOURCES
MICHAEL R. STYLER
GARY R.HERBERT Executive Director
Governor Division of Oil, Gas and MiningSPENCER J. COX JOHN R. BAZALieutenant Governor Division Director
February 7, 2017
Crescent Point Energy U.S. Corp.555 17th Street, Suite 750Denver, CO 80202
Re: APDs Rescinded for Crescent Point Enerav U.S. Corp, Uintah County
Ladies and Gentlemen:
Enclosed find the list of APDs that is being rescinded. No drilling activityat these locations has been reported to the division. Therefore, approval to drillthese wells is hereby rescinded as of February 7, 2017.
A new APD must be filed with this office for approval orior to thecommencement of any future work on the subject location.
If any previously unreported operations have been performed on this welllocation, it is imperative that you notify the Division immediately.
Sincerely,
D míaMasonEn ironmental Scientist
cc: Well FileBrad Hill, Technical Service Manager
UTAH
DNR1594 West North Temple, Suite 1210, Salt Lake City, UT 84116PO Box 145801, Salt Lake City, UT 84114-5801telephone (801) 538-5340 •facsimile (801) 359-3940•TTY (801) 538-7458 •www.ogm.utah.gov
OIL, GAS &
43-047-54088 Hicken 10-9-3-1E43-047-54089 Deep Creek 9-29-3-2E43-047-54093 Deep Creek 5-10-4-2E43-047-54094 Deep Creek 6-33-3-2E43-047-54097 Deep Creek 4-33-3-2E43-047-54098 Deep Creek Tribal 1-32-3-2E43-047-54142 Deep Creek 1-29-3-2E43-047-54082 ULT 12-5-4-2E43-047-54087 Deep Creek 5-33-3-2E43-047-54190 Deep Creek