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T R A N S M I T T A LL
FROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7
th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
RE: CD4-536, CD4-539, CD4-587
DATE: 09/30/2025
Transmitted:
CD4-536
Via SFTP
223-079
T40929
CD4-539
CD4-587
223-063
T40930
223-098
T40931
TTransmittal instructions: please promptly sign, scan, and e-mail to
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CC: CD4-536,CD4-539, CD4-587 - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services |ConocoPhillips Alaska |
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.09.30 10:07:39
-08'00'
Originated: Delivered to:5-Jul-24
Alaska Oil & Gas Conservation Commiss 05Jul24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24
CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24
2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24
1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24
CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24
CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24
3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24
2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24
2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24
2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24
MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24
MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T39122
T39123
T39124
T39125
T39126
T39127
T39128
T39129
T39130
T39131
T39132
T39133
CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.05 10:30:21 -08'00'
Originated: Delivered to:19-May-24
Alaska Oil & Gas Conservation Commiss 19May24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24
3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24
3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24
2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24
MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24
MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24
3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24
2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24
1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24
1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24
1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24
3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24
2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24
CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
Eset #
T38800
T38801
T38802
T38803
T38816
T38817
T38818
T38819
T38820
T38821
T38822
T38824
T38823
T38825CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.20 12:41:13 -08'00'
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CD4-536 COLVILLE RIVER MWD/LWD/DD VISION SERVICES FINAL FIELD 13-Nov-23 1
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50-103-20863-00-00 223-079
PTD:223-079
T38499
Kayla Junke 2/14/2024
CD4-536
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.14
11:21:09 -09'00'
TT RR AA NN SS MM II TT TT AA LL
FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 7
th Avenue, Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska
RE:CD4-536
DATE: 02/01/2024
Transmitted:
North Slope, Colville River Unit, Alaska
Via SFTP upload
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: CD4-536 e-transmittal well folder
Receipt: Date:
Alaska/IT Data Services-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
CD4-536
PTD: 223-079
T38483
2/5/2024
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.05
10:45:49 -09'00'
T R A N S M I T T A LL
FROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7
th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
RE: CD4-536, CD4-539, CD4-587
DATE: 08/06/2025
Transmitted:
GeoSphere Data Via SFTP
223-079
T40736
223-063
T40737
Transmittal instructions: please promptly sign, scan, and e-mail to
AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM
CC: CD4-536, CD4-539, CD4-587 e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services |ConocoPhillips Alaska |
223-098
T40738
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2025.08.07 08:00:47
-08'00'
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________
ConocoPhillips Alaska Inc. Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 20,958 feet feet
true vertical 4,266.10 feet feet
Effective Depth measured 20,958 feet 11,926.7/12,069.8 feet
true vertical 4266.1 feet 4034/4045 feet
Perforation depth Measured depth NA feet
True Vertical depth NA feet
Tubing (size, grade, measured and true vertical depth) 4.5" 12.6 # L-80 12065'MD 4044' TVD
SLZXP LTP 12069.8' MD 4045' TVD
Packers and SSSV (type, measured and true vertical depth) TNT 11,926.7' MD 4034' TVD
SSSV - SLB TRMAXX-5E 1575.9' MD 1552' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Robert Blakney
Contact Email:Robert.g.blakney@conocophillips.com
Authorized Title: Compeltion Engineer Contact Phone:
2630 2412.6
Burst Collapse
2,260
5,090
4790, 11,080
5020
8150
6890, 12,620
measured
TVD
Production
Liner
7839
4685
8900.4
Casing
Structural
3467.8
4070.2
4.5"
7839
12380
20958 2466.1
Plugs
Junk measured
2,745,600 lbs of 20/40 Wanli Cermaic, 82,000 lbs of 100Mesh sand, & 1,012,175 gals of seawater. Final pressure 2,935 psi @ BHG
Length
133
2630
133Conductor
Surface
Intermediate
20"x 34"
13-3/8"
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL380077, ADL384211, ADL380082, ADL388903, ADL391587
Qannik Oil pool
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-079
5010320863
Size
133
NA
9-5/8"
11,590
7-5/8"
P.O. Box 100360 Anchorage, AK 99510 -03603. Address:
CD4-536
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
TBD
Gas-Mcf
MD
12808-20785
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
323-632
Sr Pet Eng:
9,210
Sr Pet Geo: Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
907-947-8498
Qannik oil pool
Development Service
GINJ SUSP SPLUG
Gas
WINJ WAG
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Dec 13th, 2023
By Grace Christianson at 2:04 pm, Dec 14, 2023
Prepared By:
William Martin
James Campbell
Nannook Crew
Intervals 1-23
Notice: Although the information contained in this report is based on sound engineering practices, the copyright
owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage
arising from the possession or use of the report whether in terms of correctness or otherwise. The application,
CD4-536
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20863
Prepared for: Robert Blakeny
December 5, 2023
Narwal Formation
30# Delta
Table of Contents
Section Page(s)
Cover
TOC
Executive Summary
Wellbore Information
Actual Design
Interval Summary
Fluid System-Proppant Summary
Interval 1 Plots
Interval 2 Plots
Interval 3 Plots
Interval 4 Plots
Interval 5 Plots
Interval 6 Plots
Interval 7 Plots
Interval 8 Plots
Interval 9 Plots
Interval 10 Plots
Interval 11 Plots
Interval 12 Plots
Interval 13 Plots
Interval 14 Plots
Interval 15 Plots
Interval 16 Plots
Interval 17 Plots
Interval 18 Plots
Interval 19 Plots
Interval 20 Plots
Interval 21 Plots
Interval 22 Plots
Interval 23 Plots
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 12-3
Water Straps 12-4
Water Straps 12-5
Water Analysis 12-3
Water Analysis 12-4
Water Analysis 12-5
Real-Time QC 1
Real-Time QC 2
Event Log 12-3
Event Log 12-4
Event Log 12-5
Prejob Break Test
Fann 15 Min Test Zone 1
Fann 15 Min Test Zone 2
Fann 15 Min Test Zone 3
Fann 15 Min Test Zone 4
Fann 15 Min Test Zone 5
Fann 15 Min Test Zone 6
Fann 15 Min Test Zone 7
Fann 15 Min Test Zone 8
Fann 15 Min Test Zone 9
Fann 15 Min Test Zone 12
Fann 15 Min Test Zone 13
Fann 15 Min Test Zone 14
Fann 15 Min Test Zone 15
Fann 15 Min Test Zone 16
Fann 15 Min Test Zone 17
Fann 15 Min Test Zone 18
Fann 15 Min Test Zone 19
Fann 15 Min Test Zone 20
Fann 15 Min Test Zone 21
Sand Sieve Analysis
109 - 112
101 - 108
1
2
3
4
5 - 9
55 - 58
59 - 62
63 - 66
10 - 37
38
39 - 50
51 - 54
67 - 74
75 - 78
97 - 100
79 - 82
83 - 86
87 - 89
90 - 92
93 - 96
113 - 116
117 - 120
121 - 124
125 - 128
129 - 132
133 - 136
137 - 139
140 - 143
144
145
146
147 - 150
151
152
153
154
155
156
157
158
159 - 160
161 - 162
163 - 164
165
166
167
168
169
170
171
172
173
174
175
176
177
178
179
180
181
182
183
184
185 - 186
Conoco Phillips - CD4-536 TOC 2
896,536 gallons of 30# Delta Frac
80,190 gallons of 30# Linear
3,000 gallons of Freeze Protect
2,700,600 pounds of Wanli 20/40 Ceramic
81,000 pounds of 100M
925,678 gallons of 30# Delta Frac
86,497 gallons of 30# Linear
748 gallons of Freeze Protect
2,745,600 pounds of Wanli 20/40 Ceramic
82,000 pounds of 100M
Thank you,
Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may
have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions
provider for future projects.
Engineering Executive Summary
On December 02, 2023 a stimulation treatment was performed in the Narwal formation on the CD4-536 well in Harrison Bay
County, AK. The CD4-536 was a 23 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 23 of 23 stages. 0 stages were skipped, 0 stages screened out and 0 stages were cut short
A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided
to summarize events and changes to the proposed treatment:
This well consisted of 20 proppant fracs and 3 dart drops, all intervals were succesfully completed. Darts were dropped for
interval 10, 11, and 22/23. The sleeves for intervals 22 and 23 were within the same top and bottom packers, Sleeve 22 was
opened first and the fracture treatment was pumped through sleeve 23. Intervals 1 and 2 were pumped with a max proppant
concentration of 6 ppg, while interval 3 was pumped with a designed max of 7 pppg, Interval 4 through 9 had a max proppant
concentration of 8 ppg, interval 13-14 had a designed max of 9 ppg, and the remaining intervals had a designed max proppant
concentration of 10 ppg. The final interval was increased in design by 20 klbs and reached a max proppant concentration of 12
ppg.
Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid
volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are
performed before each job in order to optimize the performance of the treatment fluids.
William Martin
Senior Technical Professional
Conoco Phillips - CD4-536 Executive Summary 3
Conoco Phillips - CD4-536 Wellbore Information 4
Interval 1Narwhal@ 20785.61 - 20789.47 ft 94.9 °FInterval 2Narwhal@ 20390.16 - 20394.02 ft 94.9 °FInterval 3Narwhal@ 20037.8 - 20041.66 ft 94.8 °FInterval 4Narwhal@ 19651.28 - 19655.14 ft 94.8 °FInterval 5Narwhal@ 19258.76 - 19262.62 ft 94.9 °F
Interval 6Narwhal@ 18867.98 - 18871.84 ft 94.8 °FInterval 7Narwhal@ 18476.15 - 18480.01 ft 94.7 °FInterval 8Narwhal@ 18122.27 - 18126.13 ft 94.8 °F
Interval 9Narwhal@ 17728.32 - 17730.37 ft 94.8 °FInterval 10Narwhal@ 17335.4 - Interval 11Narwhal@ 16902.2 - Interval 12Narwhal@ 16590.68 - 16592.73 ft 94.7 °FInterval 13Narwhal@ 16195.9 - 16197.95 ft 94.6 °FInterval 14Narwhal@ 15805.5 - 15807.55 ft 94.6 °F
Interval 17Narwhal@ 14663.88 - 14665.93 ft 94.3 °FInterval 16Narwhal@ 15057.08 - 15059.13 ft 94.4 °FInterval 18Narwhal@ 14268.85 - 14270.9 ft 94.3 °FInterval 15Narwhal@ 15452.88 - 15454.93 ft 94.5 °F
Interval 19Narwhal@ 13955.84 - 13957.89 ft 94.3 °FInterval 20Narwhal@ 13601.85 - 13603.9 ft 94.3 °FInterval 21Narwhal@ 13247.84 - 13249.89 ft 94.2 °FInterval 22Narwhal@ 12976.06 -Interval 23Narwhal@ 12808.2 - 12810.25 ft 94 °F
12/3/23 10:16
12/3/23 11:46
90 min
12.2 bpm
4,098 psi
4,581 psi
21 bbl
24.9 bpm
3,555 psi
4,046 psi
23.0 bpm
3,127 psi
3,118 psi
3,756 psi
1,761 hhp
480 psi
400 psi
548 psi
6.16 ppg
5
5
28 %
30 %
23 cP
84.4 F
8.5
MiniFrac
23.440 bpm
2595 psi
3391 psi
24.29 bpm
2879 psi
3589 psi
2625 psi
0.624 psi/ft
2597 psi
2589 psi
2584 psi
147,052 lbs
4,924 lbs
151,976 lbs
151,931 lbs
Minifrac Max Surface Pressure:
100M Pumped:
Final 15 min:
Proppant in Formation:
Minifrac Max DH Pressure:
Final 5 min:
Dart/Ball Early :
Average pH:
Minifrac Average Rate:
Pump Time:
Pad Percentage Actual
Wanli 20/40 Ceramic Pumped:
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
CD4-536 - Narwal - Interval 1
Interval Summary
Start Date/Time:
End Date/Time:
Average Missile Pressure:
Open Well Pressure:
Initial OA Pressure:
Average Surface Pressure:
Average Rate:
Max OA Pressure:
Pumps Starting Stage:
Pad Percentage Design
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pumps Ending Stage:
Max Proppant Concentration:
Diagnostic method
Minifrac Max Rate:
ISDP:
Final Fracture Gradient:
Final 10 min:
Proppant Summary
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Total Proppant Pumped* :
Conoco Phillips - CD4-536 Interval Summary 10
80,546 gal 1,918 bbls
13,584 gal 323 bbls
248 gal 6 bbls
1,043 gal 25 bbls
8,245 gal 196 bbls
11,550 gal 275 bbls
41,111 gal 979 bbls
3,634 gal 87 bbls
4,697 gal 112 bbls
3,963 gal 94 bbls
6,303 gal 150 bbls
13,462 gal 321 bbls
122 gal 3 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Displace Dart to Seat Volume:
Pad Volume:
30# Delta Frac Volume:
30# Linear Volume:
Spacer and Dart Drop Volume:
Interval Status:
Nate Brzezinski
James Campbell
Minifrac - Establish Fluid Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Interval 01 was initiated with popping the arsenal burst disk, it popped at 5144 psi on surface,
7052 psi BH. A Minifrac was pumped and decline was observed for 50 minutes. Decision was
made to increase 100M volume to 5,000 lb and take the volume from pad. Stage was pumped
to completion.
Minifrac - Flush Volume:
Arsenal Sleeve Shift Volume:
Freeze Protect Volume:
Greg Clayton
William Martin
Minifrac - Treatment Volume:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Conoco Phillips - CD4-536 Interval Summary 11
12/3/23 11:46
12/3/23 12:55
69 min
12.2 bpm
5,403 psi
5,727 psi
9 bbl
23.8 bpm
3,553 psi
3,964 psi
23.1 bpm
3,263 psi
3,252 psi
3,840 psi
1,845 hhp
510 psi
549 psi
6.34 ppg
5
5
28 %
29 %
25 cP
87.6 F
8.4
149,209 lbs
3,504 lbs
152,713 lbs
152,713 lbs
60,257 gal 1,435 bbls
13,845 gal 330 bbls
10,018 gal 239 bbls
8,982 gal 214 bbls
41,257 gal 982 bbls
849 gal 20 bbls
12,996 gal 309 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Pad Percentage Design
Pad Percentage Actual
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
CD4-536 - Narwal - Interval 2
Average BH Pressure:
Average Missile HHP:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pumps Starting Stage:
Pumps Ending Stage:
Average Visc:
Average Temp:
Average pH:
Proppant Summary
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
30# Delta Frac Volume:
30# Linear Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Dart Drop Volume:
Flush Volume:
Interval Status:
100 Mesh was dropped from the 5,000 lb change made in the Minifrac to the original 4000 lb
design. Stage was pumped as per design, however, while loading the dart, the roto launcher
malfunctioned and two darts were loaded on top of each other. Decision was made to shut
down and ensure proper loading of the dart.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
William Martin
Nate Brzezinski
James Campbell
Conoco Phillips - CD4-536 Interval Summary 12
12/3/23 13:16
12/3/23 14:46
90 min
12.1 bpm
4,427 psi
5,169 psi
11 bbl
23.8 bpm
3,611 psi
3,962 psi
22.6 bpm
3,181 psi
3,171 psi
3,730 psi
1,762 hhp
520 psi
570 psi
7.26 ppg
5
5
28 %
25 %
24 cP
86.4 F
8.4
148,542 lbs
3,772 lbs
152,314 lbs
152,171 lbs
57,673 gal 1,373 bbls
4,694 gal 112 bbls
9,227 gal 220 bbls
36,257 gal 863 bbls
1,144 gal 27 bbls
6,351 gal 151 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Summary
Spacer and Ball Drop Volume:
Wanli 20/40 Ceramic Pumped:
Pad Volume:
Interval Summary
Average Missile HHP:
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Average pH:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Pad Percentage Design
Pad Percentage Actual
Average Visc:
Initial OA Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
CD4-536 - Narwal - Interval 3
End Date/Time:
Max BH Pressure:
Average Rate:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Pump Time:
Initial Rate (Breakdown):
Fluid Summary (by stage description)
Conditioning Pad Volume:
Establish Stable Fluid Volume:
30# Delta Frac Volume:
William Martin
Nate Brzezinski
James Campbell
Interval Status:
Pumping was resumed on Day 1 of pumping after removing the double loaded dart from the
roto launcher. After resuming pumping, a dart was launched, XL resumed, and the interval
started as per design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Proppant Laden Fluid Volume:
Greg Clayton
Conoco Phillips - CD4-536 Interval Summary 13
12/3/23 14:46
12/3/23 15:49
63 min
12.1 bpm
5,096 psi
5,285 psi
10 bbl
24.4 bpm
3,741 psi
4,305 psi
22.4 bpm
3,459 psi
3,445 psi
4,084 psi
1,900 hhp
520 psi
527 psi
8.60 ppg
5
4
28 %
29 %
24 cP
81.7 F
8.5
152,240 lbs
3,262 lbs
155,502 lbs
155,502 lbs
52,758 gal 1,256 bbls
7,715 gal 184 bbls
9,160 gal 218 bbls
34,856 gal 830 bbls
1,027 gal 24 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial Rate (Breakdown):
Proppant in Formation:
Max Surface Pressure:
Fluid Summary (by fluid description)
30# Delta Frac Volume:
Average Rate:
Average Missile Pressure:
Average BH Pressure:
Average Missile HHP:
Pumps Ending Stage:
Pad Percentage Actual
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Interval Summary
Start Date/Time:
Initial Surface Pressure (Breakdown):
End Date/Time:
Pump Time:
CD4-536 - Narwal - Interval 4
Max BH Pressure:
Proppant Summary
Wanli 20/40 Ceramic Pumped:
Total Proppant Pumped* :
Pad Percentage Design
Average Surface Pressure:
Pumps Starting Stage:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Average Temp:
Average pH:
Initial OA Pressure:
During the 1 ppg sand stage, pump 621 was brought down due to cutting. Rate was readjusted
and the stage continued. During the 8 ppg sand stage, pump 621 dropped due to a high
preload pressure, rate was brought back up shortly afterwards and the stage was pumped to
completion. James Campbell
Pad Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Interval Status:
Greg Clayton
William Martin
Nate Brzezinski
Conoco Phillips - CD4-536 Interval Summary 14
12/3/23 15:49
12/3/23 16:40
51 min
12.1 bpm
5,388 psi
5,862 psi
7 bbl
23.6 bpm
3,391 psi
3,786 psi
22.9 bpm
2,979 psi
2,968 psi
3,580 psi
1,671 hhp
529 psi
593 psi
8.29 ppg
4
4
28 %
29 %
24 cP
90 F
8.5
2470 psi
0.588 psi/ft
2506 psi
2490 psi
2489 psi
130,216 lbs
4,092 lbs
134,308 lbs
134,308 lbs
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Temp:
Initial Surface Pressure (Breakdown):
Max Rate:
Pump Time:
ISDP:
Pad Percentage Actual
Pumps Starting Stage:
Pumps Ending Stage:
Final Fracture Gradient:
Total Proppant Pumped* :
Initial Rate (Breakdown):
Average pH:
CD4-536 - Narwal - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Pad Percentage Design
Average Rate:
Proppant in Formation:
Final 5 min:
Average Missile HHP:
Average Visc:
Max Surface Pressure:
Interval Summary
Final 10 min:
Final 15 min:
Proppant Summary
Wanli 20/40 Ceramic Pumped:
100M Pumped:
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
Conoco Phillips - CD4-536 Interval Summary 15
42,469 gal 1,011 bbls
12,436 gal 296 bbls
4,613 gal 110 bbls
9,069 gal 216 bbls
28,787 gal 685 bbls
12,436 gal 296 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Nate Brzezinski
Stage pumped to completion and underflushed by 2 bbl when shutting down for the night.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
James Campbell
30# Delta Frac Volume:
Proppant Laden Fluid Volume:
Interval Status:
Pad Volume:
William Martin
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Conditioning Pad Volume:
30# Linear Volume:
Flush Volume:
Conoco Phillips - CD4-536 Interval Summary 16
12/4/23 8:36
12/4/23 9:55
79 min
12.1 bpm
4,874 psi
5,192 psi
14 bbl
23.9 bpm
3,513 psi
3,720 psi
22.6 bpm
3,217 psi
3,173 psi
3,570 psi
1,779 hhp
247 psi
122 psi
495 psi
8.15 ppg
5
5
28 %
32 %
24 cP
79.1 F
8.5
129,048 lbs
132,949 lbs
132,805 lbs
48,926 gal 1,165 bbls
1,349 gal 32 bbls
248 gal 6 bbls
4,352 gal 104 bbls
11,274 gal 268 bbls
27,951 gal 666 bbls
1,042 gal 25 bbls
1,349 gal 32 bbls
4,307 gal 103 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Proppant Concentration:
Pad Percentage Actual
Proppant Laden Fluid Volume:
Freeze Protect Volume:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Open Well Pressure:
Average Surface Pressure:
Max OA Pressure:
Spacer and Dart Drop Volume:
Spacer and Ball Drop Volume:
Initial OA Pressure:
Start Date/Time:
Pad Percentage Design
Average Temp:
Total Proppant Pumped* :
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average BH Pressure:
Proppant in Formation:
Conditioning Pad Volume:
Interval Status:
Average Visc:
Pumps Ending Stage:
30# Delta Frac Volume:
30# Linear Volume:
Pad Volume:
Wanli 20/40 Ceramic Pumped:
Interval 06 was pumped as per design. Good indiction showed once the dart seated and the
sleeve shifted.
William Martin
Nate Brzezinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
CD4-536 - Narwal - Interval 6
Interval Summary
Average pH:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
Pumps Starting Stage:
Max Rate:
Average Missile Pressure:
Average Rate:
Pump Time:
Initial Rate (Breakdown):
Average Missile HHP:
Conoco Phillips - CD4-536 Interval Summary 17
12/4/23 9:55
12/4/23 10:45
50 min
11.8 bpm
5,436 psi
5,706 psi
17 bbl
24.0 bpm
3,639 psi
3,891 psi
22.5 bpm
3,263 psi
3,230 psi
3,703 psi
1,803 hhp
377 psi
539 psi
8.61 ppg
5
5
28 %
28 %
24 cP
79.1 F
8.5
131,086 lbs
3,089 lbs
134,175 lbs
134,120 lbs
42,026 gal 1,001 bbls
4,531 gal 108 bbls
8,520 gal 203 bbls
27,939 gal 665 bbls
1,036 gal 25 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant in Formation:
Proppant Laden Fluid Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Average Visc:
Conditioning Pad Volume:
Average BH Pressure:
Average Surface Pressure:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Wanli 20/40 Ceramic Pumped:
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Average Temp:
Average Missile HHP:
Average pH:
Max Proppant Concentration:
Pad Volume:
Spacer and Dart Drop Volume:
Pump Time:
CD4-536 - Narwal - Interval 7
End Date/Time:
Dart/Ball Early :
Pad Percentage Actual
Initial OA Pressure:
Pad Percentage Design
Pumps Starting Stage:
Proppant Summary
Pumps Ending Stage:
Interval Summary
Interval Status:
Sleeve 7 showed good signature while shifting. Stage was pumped as per design.
Fluid Summary (by fluid description)
30# Delta Frac Volume:
Greg Clayton
William Martin
James Campbell
Fluid Summary (by stage description)
Nate Brzezinski
100M Pumped:
Total Proppant Pumped* :
Conoco Phillips - CD4-536 Interval Summary 18
12/4/23 10:45
12/4/23 11:39
54 min
12.2 bpm
5,218 psi
5,519 psi
7 bbl
24.0 bpm
3,568 psi
3,876 psi
22.7 bpm
3,226 psi
3,194 psi
3,716 psi
1,795 hhp
499 psi
538 psi
8.32 ppg
5
5
28 %
30 %
24 cP
83 F
8.6
130,576 lbs
3,830 lbs
134,406 lbs
134,406 lbs
44,414 gal 1,057 bbls
4,579 gal 109 bbls
10,311 gal 246 bbls
28,540 gal 680 bbls
984 gal 23 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Sleeve 8 showed good signature while shifting. Stage was pumped as per design.
Proppant Laden Fluid Volume:
Average Visc:
Total Proppant Pumped* :
Average Temp:
Max OA Pressure:
Pumps Ending Stage:
Nate Brzezinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial OA Pressure:
Average Missile Pressure:
Max BH Pressure:
Dart/Ball Early :
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Max Surface Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Initial BH Pressure (Breakdown):
30# Delta Frac Volume:
Max Rate:
Interval Summary
CD4-536 - Narwal - Interval 8
Pumps Starting Stage:
Average Rate:
Max Proppant Concentration:
Average BH Pressure:
Average pH:
Average Surface Pressure:
Pad Volume:
Proppant Summary
Conditioning Pad Volume:
Average Missile HHP:
Fluid Summary (by stage description)
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Fluid Summary (by fluid description)
Pad Percentage Actual
Pad Percentage Design
Spacer and Dart Drop Volume:
Proppant in Formation:
Interval Status:
William Martin
Greg Clayton
Conoco Phillips - CD4-536 Interval Summary 19
12/4/23 11:39
12/4/23 12:18
39 min
12.3 bpm
5,163 psi
5,550 psi
10 bbl
24.0 bpm
3,322 psi
3,739 psi
22.6 bpm
3,555 psi
2,898 psi
3,555 psi
1,973 hhp
514 psi
539 psi
8.47 ppg
5
5
27 %
30 %
23 cP
82.4 F
8.5
130,424 lbs
4,047 lbs
134,471 lbs
134,219 lbs
43,387 gal 1,033 bbls
4,527 gal 108 bbls
9,877 gal 235 bbls
28,118 gal 669 bbls
865 gal 21 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max OA Pressure:
Good Signature for sleeve 9 shifting. Stage pumped to completion as per the design.
Interval Status:
Pad Volume:
Average Missile HHP:
Initial OA Pressure:
Average Rate:
100M Pumped:
Pad Percentage Actual
Dart/Ball Early :
James Campbell
Average Missile Pressure:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Average BH Pressure:
Interval Summary
Proppant Summary
Wanli 20/40 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Average pH:
Average Visc:
Pad Percentage Design
Total Proppant Pumped* :
Max Surface Pressure:
Max BH Pressure:
Initial Rate (Breakdown):
Proppant in Formation:
Max Rate:
Pumps Ending Stage:
Spacer and Dart Drop Volume:
30# Delta Frac Volume:
CD4-536 - Narwal - Interval 9
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Start Date/Time:
End Date/Time:
Pump Time:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
William Martin
Nate Brzezinski
Average Temp:
Max Proppant Concentration:
Pumps Starting Stage:
Average Surface Pressure:
Greg Clayton
Conoco Phillips - CD4-536 Interval Summary 20
12/4/23 12:18
12/4/23 12:31
13 min
12.0 bpm
3,490 psi
5,093 psi
16 bbl
23.8 bpm
3,322 psi
3,739 psi
21.4 bpm
2,723 psi
2,692 psi
3,555 psi
1,430 hhp
513 psi
540 psi
0.00 ppg
5
5
2658 psi
0.636 psi/ft
0 lbs
0 lbs
0 lbs
0 lbs
0 gal 0 bbls
12,222 gal 291 bbls
10,992 gal 262 bbls
1,230 gal 29 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Surface Pressure:
Spacer and Dart Drop Volume:
Displace Dart to Seat Volume:
Max Proppant Concentration:
Interval Status:
Average Rate:
100M Pumped:
Average Missile Pressure:
Wanli 20/40 Ceramic Pumped:
Initial Rate (Breakdown):
Max Surface Pressure:
Max BH Pressure:
Pumps Ending Stage:
Initial Surface Pressure (Breakdown):
Proppant Summary
Fluid Summary (by stage description)
William MartinThere was no proppant pumped during this stage as per the design, only the sleeve was
shifted. After shifting the sleeve, pumping was stopped to load a dart to pump one more
interval on the day.
Interval Summary
Pump Time:
Start Date/Time:
CD4-536 - Narwal - Interval 10
End Date/Time:
Max Rate:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
30# Linear Volume:
Average Missile HHP:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Pumps Starting Stage:
Dart/Ball Early :
30# Delta Frac Volume:
Max OA Pressure:
Average BH Pressure:
ISDP:
Final Fracture Gradient:
Nate Brzezinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Conoco Phillips - CD4-536 Interval Summary 21
12/4/23 12:39
12/4/23 12:53
14 min
12.2 bpm
1,397 psi
2,812 psi
9 bbl
23.9 bpm
2,325 psi
3,205 psi
19.6 bpm
1,960 psi
1,938 psi
3,017 psi
943 hhp
550 psi
555 psi
0.00 ppg
5
5
#DIV/0!%
#DIV/0!%
0 lbs
0 lbs
0 lbs
0 lbs
0 gal 0 bbls
11,743 gal 280 bbls
10,992 gal 262 bbls
751 gal 18 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Surface Pressure:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Pumps Starting Stage:
100M Pumped:
Max BH Pressure:
Average Rate:
Average BH Pressure:
Start Date/Time:
Interval Status:
Initial OA Pressure:
William Martin
Average Missile HHP:
30# Linear Volume:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
Pumps Ending Stage:
Pump Time:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
30# Delta Frac Volume:
CD4-536 - Narwal - Interval 11
End Date/Time:
Max Proppant Concentration:
Max Rate:
Wanli 20/40 Ceramic Pumped:
Pad Percentage Actual
Nate Brzezinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Pad Percentage Design
Average Surface Pressure:
Max OA Pressure:
Fluid Summary (by stage description)
Spacer and Dart Drop Volume:
Displace Dart to Seat Volume:
No proppant was pumped into this interval as per design, only the sleeve was shifted. Initially
there was very little indication of a sleeve shift, after bringing up rate there was a large pressure
increase indicating the initial values we saw was only a partial shift.
Greg Clayton
Conoco Phillips - CD4-536 Interval Summary 22
12/4/23 12:53
12/4/23 14:02
69 min
12.2 bpm
4,759 psi
4,850 psi
8 bbl
24.2 bpm
3,340 psi
3,545 psi
22.8 bpm
2,953 psi
2,924 psi
3,366 psi
1,649 hhp
513 psi
555 psi
9.03 ppg
5
5
32 %
35 %
25 cP
79.7 F
8.5
130,596 lbs
4,339 lbs
134,935 lbs
134,880 lbs
45,559 gal 1,085 bbls
5,025 gal 120 bbls
10,749 gal 256 bbls
23,593 gal 562 bbls
987 gal 24 bbls
5,205 gal 124 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conditioning Pad Volume:
Spacer and Dart Drop Volume:
Pad Volume:
Proppant in Formation:
Establish Stable Fluid Volume:
100M Pumped:
Max Surface Pressure:
Wanli 20/40 Ceramic Pumped:
Pumps Ending Stage:
Pad Percentage Design
Total Proppant Pumped* :
Proppant Laden Fluid Volume:
Average Temp:
Interval Status:
Good indication of the sleeve shifting. Stage pumped as per design. William Martin
Nate Brzezinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Proppant Summary
Fluid Summary (by fluid description)
30# Delta Frac Volume:
Fluid Summary (by stage description)
Average Surface Pressure:
End Date/Time:
Start Date/Time:
Average Rate:
Average Missile Pressure:
Pad Percentage Actual
Initial Rate (Breakdown):
Average BH Pressure:
Dart/Ball Early :
Max BH Pressure:
Average Visc:
Max OA Pressure:
Average pH:
Max Rate:
Initial OA Pressure:
Pumps Starting Stage:
Max Proppant Concentration:
Pump Time:
CD4-536 - Narwal - Interval 12
Interval Summary
Initial BH Pressure (Breakdown):
Average Missile HHP:
Initial Surface Pressure (Breakdown):
Conoco Phillips - CD4-536 Interval Summary 23
12/4/23 14:02
12/4/23 14:48
46 min
12.3 bpm
5,015 psi
5,345 psi
6 bbl
24.2 bpm
3,557 psi
3,555 psi
23.3 bpm
3,016 psi
2,986 psi
3,444 psi
1,722 hhp
513 psi
535 psi
9.57 ppg
5
5
32 %
35 %
24 cP
81.7 F
8.5
12605 psi
3.023 psi/ft
2665 psi
2655 psi
2646 psi
130,202 lbs
4,355 lbs
134,557 lbs
134,557 lbs
Wanli 20/40 Ceramic Pumped:
Average BH Pressure:
100M Pumped:
Max Rate:
Proppant in Formation:
Dart/Ball Early :
Pumps Ending Stage:
Average Temp:
Average Surface Pressure:
Start Date/Time:
CD4-536 - Narwal - Interval 13
Average Rate:
Final 5 min:
Final 10 min:
Pad Percentage Design
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Max Proppant Concentration:
ISDP:
Final Fracture Gradient:
Proppant Summary
Max BH Pressure:
Initial BH Pressure (Breakdown):
Average Missile Pressure:
Pump Time:
Pumps Starting Stage:
Max OA Pressure:
Average Visc:
Average pH:
Initial OA Pressure:
Average Missile HHP:
Interval Summary
End Date/Time:
Total Proppant Pumped* :
Pad Percentage Actual
Final 15 min:
Conoco Phillips - CD4-536 Interval Summary 24
38,292 gal 912 bbls
10,516 gal 250 bbls
4,898 gal 117 bbls
10,196 gal 243 bbls
23,198 gal 552 bbls
10,516 gal 250 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
30# Delta Frac Volume:
Pad Volume:
Flush Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Interval Status:
Greg Clayton
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Sleeve for interval 13 indicated a good shift. Stage was pumped as per design. This was the
final stage of day 2 of pumping.
William Martin
Nate Brzezinski
James Campbell
Fluid Summary (by fluid description)
30# Linear Volume:
Conoco Phillips - CD4-536 Interval Summary 25
12/5/23 8:10
12/5/23 9:23
73 min
12.4 bpm
3,942 psi
4,846 psi
8 bbl
24.2 bpm
2,916 psi
3,403 psi
22.8 bpm
2,490 psi
2,568 psi
3,231 psi
1,391 hhp
196 psi
377 psi
462 psi
9.34 ppg
5
5
32 %
37 %
24 cP
76 F
8.5
130,235 lbs
4,145 lbs
134,380 lbs
134,380 lbs
Max OA Pressure:
Max Proppant Concentration:
Average Surface Pressure:
Pad Percentage Actual
100M Pumped:
Pad Percentage Design
Initial Rate (Breakdown):
Pump Time:
Average pH:
Max Rate:
Max BH Pressure:
Wanli 20/40 Ceramic Pumped:
Proppant Summary
Average Rate:
Average Missile Pressure:
Pumps Ending Stage:
End Date/Time:
Average Temp:
Dart/Ball Early :
Max Surface Pressure:
Initial BH Pressure (Breakdown):
CD4-536 - Narwal - Interval 14
Average Visc:
Initial OA Pressure:
Interval Summary
Start Date/Time:
Average Missile HHP:
Open Well Pressure:
Pumps Starting Stage:
Average BH Pressure:
Initial Surface Pressure (Breakdown):
Total Proppant Pumped* :
Proppant in Formation:
Conoco Phillips - CD4-536 Interval Summary 26
47,124 gal 1,122 bbls
1,221 gal 29 bbls
252 gal 6 bbls
5,015 gal 119 bbls
11,733 gal 279 bbls
23,490 gal 559 bbls
959 gal 23 bbls
1,221 gal 29 bbls
5,927 gal 141 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Establish Stable Fluid Volume:
Interval Status:
Spacer and Dart Drop Volume:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Nate Brzezinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
During the 100 Mesh sand stage, pressure reading from the instrument skid froze, surface
pressure was read from a pump which is why it is fluctuating so much. It was fixed shortly
afterwards. Shortly before slow down for the ball, pump 584 tripped a DPM, rate was brought
up on another pump before having to slow down for Dart 15. Stage pumped to compltion.
30# Linear Volume:
Proppant Laden Fluid Volume:
Pad Volume:
Fluid Summary (by fluid description)
Freeze Protect Volume:
30# Delta Frac Volume:
William Martin
Conditioning Pad Volume:
Conoco Phillips - CD4-536 Interval Summary 27
12/5/23 9:23
12/5/23 10:09
46 min
12.4 bpm
4,485 psi
5,240 psi
10 bbl
24.2 bpm
2,944 psi
3,304 psi
22.4 bpm
2,529 psi
2,420 psi
3,144 psi
1,388 hhp
443 psi
472 psi
10.14 ppg
5
5
34 %
35 %
24 cP
76 F
8.6
133,745 lbs
4,471 lbs
138,216 lbs
138,116 lbs
37,490 gal 893 bbls
4,887 gal 116 bbls
9,726 gal 232 bbls
21,802 gal 519 bbls
1,075 gal 26 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
30# Delta Frac Volume:
Proppant Laden Fluid Volume:
Start Date/Time:
Average Surface Pressure:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Spacer and Dart Drop Volume:
Average Temp:
Average Rate:
Fluid Summary (by fluid description)
Conditioning Pad Volume:
100M Pumped:
Wanli 20/40 Ceramic Pumped:
Fluid Summary (by stage description)
Pump Time:
Initial Rate (Breakdown):
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Max Surface Pressure:
Pumps Starting Stage:
Average Visc:
Average pH:
William Martin
Nate Brzezinski
James Campbell
Greg Clayton
Average Missile HHP:
Good indication of the sleeve shifting. Stage pumped as per design.
Dart/Ball Early :
CD4-536 - Narwal - Interval 15
Interval Summary
Average Missile Pressure:
Pad Percentage Actual
Pumps Ending Stage:
Pad Percentage Design
End Date/Time:
Max BH Pressure:
Max Rate:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pad Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Interval Status:
Conoco Phillips - CD4-536 Interval Summary 28
12/5/23 10:09
12/5/23 10:55
46 min
12.4 bpm
4,456 psi
4,606 psi
11 bbl
24.3 bpm
2,851 psi
3,221 psi
22.5 bpm
2,442 psi
2,328 psi
3,065 psi
1,347 hhp
464 psi
494 psi
10.15 ppg
5
5
34 %
34 %
24 cP
77.3 F
8.6
130,760 lbs
3,897 lbs
134,657 lbs
134,624 lbs
37,560 gal 894 bbls
4,964 gal 118 bbls
9,381 gal 223 bbls
22,099 gal 526 bbls
1,116 gal 27 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Proppant in Formation:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
100M Pumped:
Wanli 20/40 Ceramic Pumped:
Average Temp:
Max BH Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Average Surface Pressure:
30# Delta Frac Volume:
Total Proppant Pumped* :
Average pH:
Fluid Summary (by fluid description)
Spacer and Dart Drop Volume:
End Date/Time:
Pumps Starting Stage:
Start Date/Time:
Average BH Pressure:
Average Rate:
Interval Summary
Pad Percentage Actual
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Missile HHP:
Max OA Pressure:
Max Proppant Concentration:
Pad Percentage Design
Average Visc:
Pump Time:
CD4-536 - Narwal - Interval 16
Max Rate:
Pumps Ending Stage:
Max Surface Pressure:
Average Missile Pressure:
Proppant Summary
Fluid Summary (by stage description)
Interval Status:
William Martin
Nate Brzezinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Interval 16 showed good sleeve shift signature. Stage pumped to completion.
Conoco Phillips - CD4-536 Interval Summary 29
12/5/23 10:55
12/5/23 11:41
46 min
12.5 bpm
2,409 psi
2,991 psi
9 bbl
23.9 bpm
2,887 psi
3,174 psi
22.3 bpm
2,444 psi
2,332 psi
3,024 psi
1,337 hhp
473 psi
499 psi
10.38 ppg
5
5
34 %
36 %
24 cP
74.1 F
8.7
131,054 lbs
3,859 lbs
134,913 lbs
134,913 lbs
37,761 gal 899 bbls
5,120 gal 122 bbls
10,034 gal 239 bbls
21,442 gal 511 bbls
1,165 gal 28 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Fluid Summary (by fluid description)
Spacer and Dart Drop Volume:
Greg Clayton
Pad Volume:
Total Proppant Pumped* :
Initial Rate (Breakdown):
Average Visc:
Average Temp:
Max OA Pressure:
Average Surface Pressure:
Max Rate:
Initial OA Pressure:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Average BH Pressure:
Fluid Summary (by stage description)
Interval 17 showed weak sleeve signature but there was a slight change. Rate was increased
to try and bump it but no large pressure changes observed. Stage pumped as per design.
William Martin
Nate Brzezinski
James Campbell
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Average Rate:
Start Date/Time:
End Date/Time:
Max Proppant Concentration:
CD4-536 - Narwal - Interval 17
Interval Summary
Average pH:
Proppant Summary
100M Pumped:
Average Missile Pressure:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Pumps Ending Stage:
Pad Percentage Design
Pad Percentage Actual
Proppant in Formation:
30# Delta Frac Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Wanli 20/40 Ceramic Pumped:
Pumps Starting Stage:
Average Missile HHP:
Pump Time:
Conoco Phillips - CD4-536 Interval Summary 30
12/5/23 11:41
12/5/23 12:28
47 min
12.3 bpm
2,446 psi
3,117 psi
12 bbl
24.0 bpm
2,605 psi
3,090 psi
22.7 bpm
2,196 psi
2,088 psi
2,945 psi
1,219 hhp
473 psi
504 psi
10.12 ppg
5
5
34 %
36 %
24 cP
75.8 F
8.7
130,650 lbs
4,135 lbs
134,785 lbs
134,785 lbs
38,818 gal 924 bbls
4,839 gal 115 bbls
10,822 gal 258 bbls
22,051 gal 525 bbls
1,106 gal 26 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Wanli 20/40 Ceramic Pumped:
Average Missile HHP:
Pad Volume:
Initial Rate (Breakdown):
Average Rate:
Conditioning Pad Volume:
Start Date/Time:
Average Surface Pressure:
Fluid Summary (by stage description)
Average Missile Pressure:
30# Delta Frac Volume:
Average Visc:
CD4-536 - Narwal - Interval 18
Pump Time:
Interval Status:
Greg Clayton
Spacer and Dart Drop Volume:
William Martin
Nate Brzezinski
James Campbell
Proppant Laden Fluid Volume:
Interval 18 showed a small but clear pressure increase indicating a sleeve shift. Stage was
pumped as per design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Max Surface Pressure:
Interval Summary
Average Temp:
Average pH:
End Date/Time:
Dart/Ball Early :
Initial BH Pressure (Breakdown):
Max Rate:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Average BH Pressure:
Initial OA Pressure:
Max OA Pressure:
Proppant Summary
Pad Percentage Design
Max Proppant Concentration:
Pad Percentage Actual
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
100M Pumped:
Pumps Starting Stage:
Pumps Ending Stage:
Conoco Phillips - CD4-536 Interval Summary 31
12/5/23 12:28
12/5/23 13:15
47 min
12.3 bpm
4,011 psi
4,539 psi
12 bbl
24.0 bpm
2,698 psi
3,110 psi
22.5 bpm
2,423 psi
2,314 psi
2,990 psi
1,333 hhp
484 psi
511 psi
10.28 ppg
5
5
34 %
37 %
25 cP
78.8 F
8.6
130,451 lbs
4,141 lbs
134,592 lbs
134,592 lbs
38,494 gal 917 bbls
5,589 gal 133 bbls
10,433 gal 248 bbls
21,435 gal 510 bbls
1,037 gal 25 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Initial BH Pressure (Breakdown):
Pad Percentage Design
Proppant Summary
Pump Time:
Initial OA Pressure:
Max OA Pressure:
Total Proppant Pumped* :
Max Proppant Concentration:
Average BH Pressure:
Max Surface Pressure:
CD4-536 - Narwal - Interval 19
Initial Surface Pressure (Breakdown):
Pad Volume:
Conditioning Pad Volume:
William Martin
Nate Brzezinski
James Campbell
Proppant in Formation:
100M Pumped:
Wanli 20/40 Ceramic Pumped:
Fluid Summary (by fluid description)
Average Surface Pressure:
Proppant Laden Fluid Volume:
Spacer and Dart Drop Volume:
Fluid Summary (by stage description)
During the 100 Mesh sand stage, BC-140X was accidentally brought to 1.0 gal/Mgal instead of
the proppant. It was quickly adjusted back to the right value but there was a slight pressure
increase observed . Stage pumped to completion.
Average Missile HHP:
Pumps Ending Stage:
30# Delta Frac Volume:
Interval Summary
Average Visc:
Start Date/Time:
End Date/Time:
Dart/Ball Early :
Pumps Starting Stage:
Max Rate:
Initial Rate (Breakdown):
Max BH Pressure:
Average Rate:
Pad Percentage Actual
Average Temp:
Average Missile Pressure:
Average pH:
Greg Clayton
Interval Status:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Conoco Phillips - CD4-536 Interval Summary 32
12/5/23 13:15
12/5/23 13:59
44 min
12.3 bpm
5,524 psi
6,102 psi
8 bbl
24.1 bpm
2,648 psi
3,082 psi
23.1 bpm
2,330 psi
2,213 psi
2,978 psi
1,317 hhp
484 psi
501 psi
10.40 ppg
5
5
34 %
34 %
23 cP
78.2 F
8.5
2713 psi
0.656 psi/ft
132,040 lbs
3,484 lbs
135,524 lbs
135,524 lbs
44,275 gal 1,054 bbls
1,237 gal 29 bbls
4,983 gal 119 bbls
8,860 gal 211 bbls
21,554 gal 513 bbls
1,237 gal 29 bbls
8,878 gal 211 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
This was the first stage pumped with the new open and close sleeve and 2880 psi shear pins.
Stage was pumped to completion and flushed to reassess if there was enough material on
location to pump the remaining intervals
Interval Status:
William Martin
Nate Brzezinski
Pad Percentage Design
Pumps Ending Stage:
Average BH Pressure:
Proppant Laden Fluid Volume:
Pumps Starting Stage:
Max Surface Pressure:
Max Proppant Concentration:
Average Visc:
Initial Rate (Breakdown):
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Pump Time:
CD4-536 - Narwal - Interval 20
Max OA Pressure:
Pad Percentage Actual
ISDP:
Average Missile HHP:
Initial OA Pressure:
Interval Summary
Start Date/Time:
End Date/Time:
Pad Volume:
Final Fracture Gradient:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
Average pH:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Proppant Summary
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Average Temp:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Flush Volume:
Total Proppant Pumped* :
Proppant in Formation:
30# Linear Volume:
30# Delta Frac Volume:
Conditioning Pad Volume:
Spacer and Dart Drop Volume:
Conoco Phillips - CD4-536 Interval Summary 33
12/5/23 15:10
12/5/23 16:15
65 min
12.3 bpm
4,808 psi
5,338 psi
5 bbl
24.1 bpm
2,990 psi
3,070 psi
22.6 bpm
2,462 psi
2,399 psi
2,943 psi
1,366 hhp
776 psi
383 psi
459 psi
10.53 ppg
5
5
34 %
36 %
23 cP
76.7 F
8.4
130,630 lbs
4,229 lbs
134,859 lbs
134,859 lbs
40,014 gal 953 bbls
4,727 gal 113 bbls
10,416 gal 248 bbls
21,242 gal 506 bbls
999 gal 24 bbls
2,630 gal 63 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Total Proppant Pumped* :
30# Delta Frac Volume:
Establish Stable Fluid Volume:
Interval 21 dart showed good indication of sleeve shift, stage pumped to completion.
Max BH Pressure:
Pad Volume:
CD4-536 - Narwal - Interval 21
Nate Brzezinski
James Campbell
Greg Clayton
Interval Status:
Max Proppant Concentration:
Pad Percentage Design
Max Surface Pressure:
Average pH:
Average BH Pressure:
Pumps Starting Stage:
William Martin
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Pad Percentage Actual
Average Rate:
Spacer and Dart Drop Volume:
Proppant in Formation:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial OA Pressure:
Open Well Pressure:
Max OA Pressure:
100M Pumped:
Average Missile HHP:
Pumps Ending Stage:
Average Visc:
Interval Summary
Proppant Summary
Wanli 20/40 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Start Date/Time:
End Date/Time:
Pump Time:
Conoco Phillips - CD4-536 Interval Summary 34
12/5/23 16:15
12/5/23 16:28
13 min
12.4 bpm
5,482 psi
5,643 psi
8 bbl
24.0 bpm
2,755 psi
3,048 psi
17.4 bpm
2,487 psi
2,419 psi
2,935 psi
1,059 hhp
459 psi
s484 psi
0.00 ppg
5
5
0 lbs
0 lbs
0 lbs
0 lbs
9,385 gal 223 bbls
0 gal 0 bbls
8,243 gal 196 bbls
1,142 gal 27 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Displace Dart to Seat Volume:
30# Delta Frac Volume:
Interval Status:
100M Pumped:
Initial Rate (Breakdown):
CD4-536 - Narwal - Interval 22
Proppant Summary
Greg Clayton
Wanli 20/40 Ceramic Pumped:
Max Proppant Concentration:
Initial Surface Pressure (Breakdown):
Spacer and Dart Drop Volume:
30# Linear Volume:
Interval Summary
Dart/Ball Early :
Average Missile Pressure:
Initial OA Pressure:
Average Surface Pressure:
Max OA Pressure:
Max Surface Pressure:
Average Missile HHP:
Average BH Pressure:
Max BH Pressure:
Max Rate:
Start Date/Time:
End Date/Time:
Pump Time:
Average Rate:
Pumps Starting Stage:
Pumps Ending Stage:
Initial BH Pressure (Breakdown):
Total Proppant Pumped* :
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
No proppant was pumped during this interval. Only a dart was displaced to open a sleeve.
Sleeve showed good signature of opening.
William Martin
Nate Brzezinski
James Campbell
Proppant in Formation:
Conoco Phillips - CD4-536 Interval Summary 35
12/5/23 16:28
12/5/23 17:15
47 min
12.4 bpm
5,216 psi
5,374 psi
4 bbl
24.3 bpm
2,821 psi
2,992 psi
23.4 bpm
2,419 psi
2,358 psi
2,944 psi
1,387 hhp
481 psi
516 psi
12.74 ppg
5
5
31 %
34 %
24 cP
79 F
8.5
2935 psi
0.716 psi/ft
2748 psi
2739 psi
2730 psi
Max BH Pressure:
Average Rate:
Max Surface Pressure:
Pad Percentage Design
Average pH:
Average Surface Pressure:
Max Proppant Concentration:
Initial OA Pressure:
Pumps Starting Stage:
Initial BH Pressure (Breakdown):
CD4-536 - Narwal - Interval 23
Initial Rate (Breakdown):
Start Date/Time:
Average Missile HHP:
Average Visc:
Average Temp:
Final 15 min:
Final Fracture Gradient:
ISDP:
End Date/Time:
Interval Summary
Pad Percentage Actual
Initial Surface Pressure (Breakdown):
Max Rate:
Average BH Pressure:
Pump Time:
Pumps Ending Stage:
Max OA Pressure:
Average Missile Pressure:
Dart/Ball Early :
Final 10 min:
Final 5 min:
Conoco Phillips - CD4-536 Interval Summary 36
151,392 lbs
6,462 lbs
157,854 lbs
157,854 lbs
38,450 gal 915 bbls
8,344 gal 199 bbls
4,783 gal 114 bbls
10,433 gal 248 bbls
23,234 gal 553 bbls
8,344 gal 199 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Proppant in Formation:
30# Delta Frac Volume:
Wanli 20/40 Ceramic Pumped:
30# Linear Volume:
Total Proppant Pumped* :
William Martin
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
The original design was changed to include an additional 11 and 12 ppg stage. A maximum
proppant concentration of 12.7 was reached before calling flush. Stage was pumped to
completion and well was successfully underflushed 2bbl.
Flush Volume:
100M Pumped:
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Interval Status:
Nate Brzezinski
Conoco Phillips - CD4-536 Interval Summary 37
Hydraulic Fracturing Fluid Product Component Information Disclosure
2023-12-03
Alaska
HARRISON BAY
50-103-20863
CONOCOPHILLIPS
CD4 536
-150.9923
70.2916
NAD83
none
Oil
4206
1012175
Hydraulic Fracturing Fluid Composition:
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number
(CAS #)
Maximum Ingredient
Concentration in
Additive (% by mass)**
Maximum
Ingredient
Concentration
in HF Fluid (%
by mass)**
Ingredient Mass
lbs Comments Company
First
Name Last Name Email Phone
SEAWATER (SG
8.52) Halliburton Base Fluid Water 7732-18-5 100.00%74.95227%8623731 Density = 8.52 Halliburton
BC-140 X2 Halliburton Initiator Listed Below Listed Below 0
BE-6(TM)
Bactericide Halliburton Microbiocide Listed Below Listed Below 0
LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA
MO-67 Halliburton pH Control Listed Below Listed Below 0
OPTIFLO-HTE Halliburton Breaker Listed Below Listed Below 0 NA
WG-36
GELLING
AGENT Halliburton Gelling Agent Listed Below Listed Below 0
Ceramic
Proppant - Wanli Wanli Proppant Listed Below Listed Below 0 NA
Sand-Common
White-100 Mesh,
SSA-2 Halliburton Proppant Listed Below Listed Below 0
Calcium Chloride Customer Salt Solution Listed Below Listed Below 0 NA
GPT 3000-3014 ResMetrics Tracer Listed Below Listed Below 0 NA
OPT 2000-2050 ResMetrics Tracer Listed Below Listed Below 0 NA
WPT 1000-1050 ResMetrics Tracer Listed Below Listed Below 0 NA
Ingredients
Listed
Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00065%75
2,7-Naphthalenedisulfonic acid, 3-
hydroxy-4-[(4-sulfor-1-
naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00004%5
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00130%150
C.I. Pigment Red 5 6410-41-9 1.00%0.00019%23
Calcium Chloride 10043-52-4 100.00%0.08865%10200
Confidential Proprietary 10.00%0.00016%19 ResMetrics Product Stewardship
info@resmetr
ics.com 8325921900
Confidential Proprietary 100.00%0.00318%366 ResMetrics Product Stewardship
info@resmetr
ics.com 8325921900
Corundum 1302-74-5 65.00%15.51102%1784640
Crystalline silica, quartz 14808-60-7 100.00%0.71854%82672
Cured acrylic resin Proprietary 1.00%0.00019%23
Denise Tuck,
Halliburton, 3000
N. Sam Houston
Pkwy E.,
Houston, TX
77032, 281-871-
6226 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Ethanol 64-17-5 60.00%0.03904%4492
Ethylene glycol 107-21-1 30.00%0.01086%1250
Glycol Ether Proprietary 85.00%0.00130%150 ResMetrics Product Stewardship
info@resmetr
ics.com 8325921900
Guar gum 9000-30-0 100.00%0.24392%28065
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.01952%2246
Hemicellulase 9025-56-3 5.00%0.00097%112
Monoethanolamine borate 26038-87-9 100.00%0.03620%4166
Mullite 1302-93-8 45.00%10.73840%1235520
Naphthalene 91-20-3 5.00%0.00325%375
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01952%2246 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Oxyalkylated phenolic resin Proprietary 10.00%0.00651%749 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched 127087-87-0 5.00%0.00325%375
Polyamine Proprietary 30.00%0.00584%672 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Propylene Glycol 57-55-6 20.00%0.00032%37
Sodium chloride 7647-14-5 5.00%3.74773%431200
Sodium hydroxide 1310-73-2 30.00%0.00340%391
Walnut hulls NA 100.00%0.01947%2240 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Water 7732-18-5 100.00%0.02346%2699
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.3
All component information listed was obtained from the suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier
who provided it. The Occupational Safety and Health Administrations (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for
how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D.
Production Type:
True Vertical Depth (TVD):
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
Well Name and Number:
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Fracture Date
State:
County:
API Number:
Operator Name:
Page 1/1Procedure CloseoutCD4-536Primary Job TypeINITIAL COMPLETIONStart Date12/2/2023End Date12/6/2023Final Job StatusCOMPLETEDTotal Time Log Hours (hr)87.97SummaryNetwork/Order Number Project Desc Estimator10451711 CD4-539 Frac/FlowbackStart Date ZX Code Time Log Hrs (hr)Cum Time Log (days) Last 24hr Sum12/2/2023 ZX02 Fracturing 10.00 0.42 RIG UP LAUNCHER & LAUNCH VALVES, MAKE UP DOWN JOINT TO GOAT HEAD. MAKE SCAFFOLD MODIFICATIONS. SPOT IN AND RIG UP BALL LAUNCH PUMP. CASTLES LOADED WITH SAND AND WATER TANKS ARE FULL AND HEATED. IN PROGRESS12/3/2023 ZX02 Fracturing 17.99 1.17 SHEAR ARSENAL DISC @ 5144 PSI. DROP STAGE #1 DART & PUMP MINI FRAC. Pc=~2682 PSI. STIMULATE STAGES 1 - 5 PER DESIGN w/ RESMETRIC TRACER ADDED PER SCHEDULE. SAW ALL AU SLEEVES CLEARLY SHIFT. TOTAL PROPPANT PUMPED= 747,218 LBS & TOTAL CLEAN= 7948 BBLS. IN PROGRESS12/4/2023 ZX02 Fracturing 23.99 2.17 STIMULATE STAGES 6 - 9 PER DESIGN. DROPPED AU DARTS FOR STAGES 10 & 11 TO SHIFT SLEEVES, BUT DID NOT STIMULATE. STIMULATE STAGES 12 & 13 PER DESIGN. ALL AU DART SIGNATURES WERE OBSERVED. TOTAL PROPPANT PUMPED = 806,428 LBS & TOTAL CLEAN VOLUME = 7103 BBLSIN PROGRESS12/5/2023 ZX02 Fracturing 23.99 3.17 STIMULATE STAGES #14 - #20 PER DESIGN AT A MAX PROPPANT CONCENTRATION OF 10.0 PPGSHUT DOWN TO FINISH BLOWING OFF LAST OF JOB PROPPANT & LOAD REMAINING 3 AU DARTS. STIMULATE STAGE 21 PER DESIGN. OPEN STAGE #22 SLEEVE ONLY & STIMULATE FINAL STAGE #23 UP TO A MAX CONCENTRATION OF 12.7 PPG. ALL AU DARTS SIGNATURES WERE OBSERVED (STAGE 17 & 18 HAD WEAK SIGNATURES) & RESMETRIC TRACER WAS ADDED PER SCHEDULE. TOTAL PROPPANT PUMPED = 1,239,780 LBS & TOTAL CLEAN VOL=9,028 BBLS. FRAC COMPLETE & BEGIN RIGGING DOWN. IN PROGRESS12/6/2023 ZX02 Fracturing 12.00 3.67 RIG DOWN ALL EQUIPMENT OFF WELLHEAD & BREAK DOWN TANK FARM AND PUMPING EQUIPMENT. ALL EQUIPMENT READY TO MOVE. JOB COMPLETE
TT RR AA NN SS MM II TT TT AA LL
FROM:: Sandra D. Lemke, ATO-704 TO:: Kayla Junke ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 7th Avenue, Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska
RE: CD4-536
DATE: 12/21/2023
Transmitted:
North Slope, Colville River Unit, Alaska
Via SFTP upload
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: CD4-536 e-transmittal well folder
Receipt: Date:
Alaska/IT Data Services-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 223-079
T38237
12/21/2023
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.12.21
09:17:41 -09'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address:7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:2297' FSL, 1488' FEL S29 T11N R5E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 18.3 BF:
Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI:x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth:x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20"X65 133'
13-3/8 L-80 2413'
9-5/8"T-95 3468'
7-5/8"L-80 4070'
4 1/2"P11O 4206'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production:Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
1576'MD/1548'TVD
Oil-Bbl:Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test:Oil-Bbl:
Flow Tubing
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Liner ( Ran 11/15/2023): 12058'MD/4044'TVD - 20958'MD/4206'TVD
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
54'
54'
Per 20 AAC 25.283 (i)(2) attach electronic information
47
12380'
51'
3448'
94
68
133
51'7839'
SIZE DEPTH SET (MD)
10 Yards
PACKER SET (MD/TVD)
12058'
42"
12.6
5957334
Colville River Field/ Qannik Oil Pool
ADL380077, ADL384211, ADL380082,
ADL380082, ADL388903, ADL391587
LONS 97-007
54'
29.7
54'
7695'
2630'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
WT. PER
FT.GRADE
386932
390902
CEMENTING RECORD
5952009
1201'MD/1193'TVD
SETTING DEPTH TVD
5944928
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
GR, RES, DEN, DIR, NEU, POR, SONIC, CALIPER, Mud Log
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
11/19/2023 223-079/323-632
50-103-20863-00-00
CRU CD4-536
10/10/2023
20995'MD/4207'TVD
N/A
72.3
P.O.Box 100360, Anchorage, AK 99510-0360
377809
2199' FSL, 433' FEL S24 T11N R4E
555' FSL, 2713' FEL S33 T11N R5E
11/11/2023
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Tail: 145bbls of 15.8ppg Class G8.5"x9 .5"
TUBING RECORD
20958'
Tail: 165.9bbls of 15.8ppg Class G
4044'
12-1/4"
6.5"
12065'4.5 11927'MD/4033' TVD
12070'MD/4045' TVD
BOTTOM
16"Lead: 377bbls of 11ppg Class G
Tail: 73.7bbls of 15.8 Class G
CASING
G
s d 1b
0 D p
op and B om; Per
L
s
(a
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 1:15 pm, Dec 12, 2023
Completed
11/19/2023
JSB
RBDMS JSB 121223
GDSR-1/26/24
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1201 1193
C-40 2353 2215
2680 2446
3296 2767
C-10 4723 3026
K3 10526 3849
4089
4208
31. List of Attachments:
Directional Survey, Well Schematic, Cement Operations, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Justin Cremer
Digital Signature with Date:
Contact Phone:907-263-4314
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
C-30
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Contact Email:justin.cremer@conocophillips.com
Authorized Title: Drilling Engineer
C-20
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Formation Name at TD:
Narwhal
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)FORMATION TESTS
Top of Productive Interval:
Narwhal
N
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
12700
20995
Page 1/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/8/2023
15:00
10/8/2023
16:00
1.00 MIRU, MOVE MOB P Walked pits away from the sub base.
Moved & staged with truck.
0.0 0.0
10/8/2023
16:00
10/8/2023
17:00
1.00 MIRU, MOVE MOB P Skidded the rig floor from over the BOP
module to the sub base into transport
position.
0.0 0.0
10/8/2023
17:00
10/8/2023
18:00
1.00 MIRU, MOVE MOB P Unpin sub base from BOP module.
Moved sub base away from the BOP
module. Turned the wheels & crab over
towards the end of the pad out of the
way to spot BOP module over CD4-536.
0.0 0.0
10/8/2023
18:00
10/8/2023
19:00
1.00 MIRU, MOVE MOB P Installed moving tongue onto the BOP
module. Prepped to pull BOP module off
of CD4-539.
0.0 0.0
10/8/2023
19:00
10/8/2023
21:00
2.00 MIRU, MOVE MOB P Prepped & moved BOP module off of
CD4-539.
0.0 0.0
10/8/2023
21:00
10/9/2023
00:00
3.00 MIRU, MOVE MOB P Moved BOP module over CD4-536.
Lowered stompers & leveled module.
0.0 0.0
10/9/2023
00:00
10/9/2023
03:00
3.00 MIRU, MOVE MOB P Crabbed sub base into position with
BOP module & rotated wheels.
0.0 0.0
10/9/2023
03:00
10/9/2023
06:00
3.00 MIRU, MOVE MOB P Leveled dirt behind CD4-536 cellar &
adjusted stompers.
0.0 0.0
10/9/2023
06:00
10/9/2023
07:00
1.00 MIRU, MOVE MOB P Skidded rig floor over BOP module into
drill position.
0.0 0.0
10/9/2023
07:00
10/9/2023
08:00
1.00 MIRU, MOVE MOB P Walked pipe shed into place with sub
base. Leveled & rigged up same.
0.0 0.0
10/9/2023
08:00
10/9/2023
09:00
1.00 MIRU, MOVE MOB P Moved pits into position along side the
sub base & began rigging it up.
0.0 0.0
10/9/2023
09:00
10/9/2023
10:00
1.00 MIRU, MOVE MOB P Moved pump module into position along
side the pits & began rigging it up.
0.0 0.0
10/9/2023
10:00
10/9/2023
12:00
2.00 MIRU, MOVE MOB P Walked the CPU into position with the
pits. Moved motors module into position.
0.0 0.0
10/9/2023
12:00
10/9/2023
18:00
6.00 MIRU, MOVE RURD P Worked on rig acceptance checklist.
Hooked up interconnects between
modules. Electrician plugged in
electrical interconnects. SIMOPS
serviced centerfugal pumps; repaired ST
-120; installed new high pressure valve
on mud pump 4.
0.0 0.0
10/9/2023
18:00
10/9/2023
20:30
2.50 MIRU, MOVE RURD P Continued with rig acceptance checklist.
Finished hooking up all interconnects.
Turned on steam, water, & air to all
modules. Rigged up MagTec equipment
& transfer lines.
Rig accepted at 20:30 hrs.
0.0 0.0
10/9/2023
20:30
10/9/2023
23:00
2.50 MIRU, MOVE NUND P Prepped conductor for nipple up.
Installed 20" diverter adapter & lower
riser section per FMC. Energized seals
& tested to 600 psi for 10 minutes, per
FMC. Made up adapter studs to FMC
specifications. SIMOPS began loading
pipe shed with 5-7/8" drill pipe.
RKB to landing ring load shoulder 54.09'
MD.
0.0 0.0
10/9/2023
23:00
10/10/2023
00:00
1.00 MIRU, MOVE NUND P Secured cellar. Installed middle section
of surface riser.
0.0 0.0
10/10/2023
00:00
10/10/2023
02:00
2.00 MIRU, MOVE NUND P Installed middle & top sections of
surface riser. Inflated air boots &
secured riser sections. SIMOPS
strapped & tallied 5-7/8" drill pipe in the
shed, loaded BHA & JARS into shed.
0.0 0.0
10/10/2023
02:00
10/10/2023
03:15
1.25 MIRU, MOVE PULD P Picked up and racked back 5-7/8" drill
pipe from the shed. Drifted with 3.75".
Ran in and tagged bottom of the
conductor at 121' MD.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 2/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/10/2023
03:15
10/10/2023
03:45
0.50 MIRU, MOVE SVRG P Serviced rig, changed out dies on ST-
120.
0.0 0.0
10/10/2023
03:45
10/10/2023
09:00
5.25 MIRU, MOVE PULD P Picked up and racked back a total of 25
stands of 5-7/8" drill pipe & 3 stands of
HWDP from the shed. Drifted with 3.75".
0.0 0.0
10/10/2023
09:00
10/10/2023
12:00
3.00 SURFAC, DRILL BHAH P Picked up 16", motor steerable, BHA 1
as per SLB DD. Made up & racked back
collar stand & JARS stand. Prep pits for
spud. Inspect all equipment.
0.0 0.0
10/10/2023
12:00
10/10/2023
13:00
1.00 SURFAC, DRILL TRIP P Ran in the hole to 120' MD. PJSM with
all team members.
0.0 120.0
10/10/2023
13:00
10/10/2023
14:00
1.00 SURFAC, DRILL SEQP P Flooded surface lines & filled
conductor / surface stack. Pressure
tested surface lines to 3500 psi.
120.0 120.0
10/10/2023
14:00
10/10/2023
18:00
4.00 SURFAC, DRILL DDRL P Drill 16" surface section from 121'-585'
MD, 585' TVD. Shot gyro surveys on
connections.
650 gpm; 1250 psi
40 rpm; Tq on 6K, off 2K
WOB 20K
PUW 122K
SOW 103K
ROT 115K
ADT 1.46, AST .27, BIT 1.46, JARS .63
120.0 585.0
10/10/2023
18:00
10/10/2023
23:00
5.00 SURFAC, DRILL DDRL P Drill 16" surface section from 585'-1141'
MD, 1135' TVD. Shot gyro surveys on
connections.
700 gpm; 1230 psi
50 rpm; Tq on 7K, off 2K
WOB 6K
PUW 125K, SOW 126K, ROT 122K
585.0 1,141.0
10/10/2023
23:00
10/10/2023
23:30
0.50 SURFAC, DRILL RGRP T Packed off CPU. Cleared cuttings tank
with Super Sucker. Checked MagTec
shipping lines. Returned to service.
1,141.0 1,141.0
10/10/2023
23:30
10/11/2023
00:00
0.50 SURFAC, DRILL DDRL P Drill 16" surface section from 1141'-
1238' MD, 1135' TVD. Shot gyro surveys
on connections.
750 gpm; 1335 psi
50 rpm; Tq on 7K, off 3K
WOB 6K
PUW 125K
SOW 126K
ROT 122K
ADT 2.61, AST 1.6, BIT 4.07, JARS 3.24
1,141.0 1,238.0
10/11/2023
00:00
10/11/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface section from 1,238'-
2,001' MD, 1,929' TVD. Shot gyro
surveys on connections.
900 gpm; 1835 psi
50 rpm; Tq on 10K, off 4K
WOB 19K, 11.2 ECD
PUW 130K, SOW 130K, ROT 127K
ADT 2.88, AST .70, BIT 6.95, JARS 6.12
1,238.0 2,004.0
10/11/2023
06:00
10/11/2023
10:30
4.50 SURFAC, DRILL DDRL P Drill 16" surface section from 2,001'- TD
at 2,637' MD, 2,411' TVD. Shot gyro
surveys on connections.
1100 gpm; 2747 psi
70 rpm; Tq on 13K, off 4K
WOB 25K, 11.44 ECD
PUW 149K, SOW 142K, ROT 145K
ADT 3.02, AST 1.38, BIT 9.97, JARS
9.14
2,004.0 2,637.0
10/11/2023
10:30
10/11/2023
12:00
1.50 SURFAC, TRIPCAS CIRC P CBU w/ BROOH 1BU per stand
1000 GPM, 2026 PSI, 60 RPM, 6K TQ,
57% FO
2,637.0 2,440.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 3/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/11/2023
12:00
10/11/2023
12:30
0.50 SURFAC, TRIPCAS OWFF P Observe well, static 30 min. 2,440.0 2,440.0
10/11/2023
12:30
10/11/2023
16:30
4.00 SURFAC, TRIPCAS BKRM P BROOH f/ 2,440' to 1,269' MD
1000 GPM, 1904 PSI, 60 RPM, 5K TQ,
55% FO
2,440.0 1,269.0
10/11/2023
16:30
10/11/2023
18:00
1.50 SURFAC, TRIPCAS PMPO P Pump OOH f/ 1,269' to 754' MD
250 GPM, 211 PSI, 15% FO
1,269.0 754.0
10/11/2023
18:00
10/11/2023
20:30
2.50 SURFAC, TRIPCAS PMPO P Pump OOH, laying in gel pill f/ 754' to
114' MD, Racking back HWDP, Jars and
DC's in derrick.. Slight PSI spikes and
increased clay at shakers, slow pulling
speed until shakers cleaned up. 250
GPM, 211 PSI, 15% FO
754.0 114.0
10/11/2023
20:30
10/11/2023
22:30
2.00 SURFAC, TRIPCAS BHAH P PJSM, LD surface BHA per DD. 114.0 0.0
10/11/2023
22:30
10/11/2023
23:00
0.50 SURFAC, TRIPCAS CLEN P Clean/Clear floor 0.0 0.0
10/11/2023
23:00
10/12/2023
00:00
1.00 SURFAC, CASING RURD P Mobilize casing equipment to floor. MU
Volant to TD, install bail extensions and
elevators.
0.0 0.0
10/12/2023
00:00
10/12/2023
01:00
1.00 SURFAC, CASING RURD P Mobilize csg equip to floor, MU Volant t/
TD, install bail extensions and elevators
per casing rep
0.0 0.0
10/12/2023
01:00
10/12/2023
06:00
5.00 SURFAC, CASING PUTB P PJSM, RIH with 13-3/8", 68#, L80, H563
casing to 1,020' MD. Backerlocked shoe
track to pin of Jt #4. Checked floats ok.
Torqued shoe track to 30K, all other
25K, dbl bumped.
0.0 1,020.0
10/12/2023
06:00
10/12/2023
08:30
2.50 SURFAC, CASING PUTB P RIH with 13-3/8", 68#, L80, H563 casing
f/ 1,020' to 2,574' MD. Torqued to 25K,
dbl bumped. Filling each joint on the fly,
topping off every 10 jts. 149K SOW.
(CBU on Jt #31, stage up to 8 BPM, 85
PSI)
1,020.0 2,574.0
10/12/2023
08:30
10/12/2023
09:30
1.00 SURFAC, CASING PUTB P MU FMC hanger and landing JT per
FMC rep. RIH and land on hanger at
2,630' MD. 218K PUW, 186K SOW.
2,574.0 2,630.0
10/12/2023
09:30
10/12/2023
11:00
1.50 SURFAC, CEMENT CIRC P Circ and cond mud for cementing. Stage
up pump rate to 8 BPM, 130 PSI, Prep
pits for cement job, PJSM with all crew
members
2,630.0 2,630.0
10/12/2023
11:00
10/12/2023
12:00
1.00 SURFAC, CEMENT CMNT P Blow down TD, RU cement hose, PT
line to 3500 PSI.
2,630.0 2,630.0
10/12/2023
12:00
10/12/2023
15:30
3.50 SURFAC, CEMENT CMNT P Mix and pump 111.5 bbls 10.5 ppg mud
push at 4.5 bpm, 100 PSI, drop bottom
plug, mix and pump 377 bbls of 11.0
ppg lead cement at 5.3 BPM, 359 PSI,
mix and pump 73.7 bbls 15.8 ppg tail
cement at 4.5 bpm, 308 PSI, drop top
plug, kick out with 20 bbls water, swap
to rig and displace cement with 362 bbls
10.5 ppg mud. Bump plug with 3047
stks with 500 psi over FCP to 1023 psi.
Hold 5 min, check floats ok, no losses
throughout job. CIP at 1522 hrs
2,630.0 2,630.0
10/12/2023
15:30
10/12/2023
17:00
1.50 SURFAC, CEMENT RURD P LD landing Jt, RD casing equip. Clean
clear floor.
0.0 0.0
10/12/2023
17:00
10/12/2023
18:30
1.50 SURFAC, CEMENT WWWH P MU stack washer and 2 Jts 5-7/8" DP,
wash riser with black water at max rate,
jet flowline, bell nipple and flow box until
clean. Cont clean and clear floor. LD 2
Jts DP and stack wash tool.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 4/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/12/2023
18:30
10/12/2023
19:45
1.25 SURFAC, CEMENT CLEN P Drain surface riser, clean flow box, ND
surface riser.
SIMOPS: Change TD grabber dies,
inspect saver sub, finnish cleaning
cement valves
0.0 0.0
10/12/2023
19:45
10/12/2023
23:00
3.25 SURFAC, WHDBOP NUND P ND surface adapter and rack back on
storage stump. Clean out conductor
valves and hanger flutes, NU FMC
wellhead per FMC rep, orientation
verified by pad operator. Tested seals to
1,000 psi for 10 min. Co Rep witnessed.
Set lower test plug. TOC 23" below
flutes.
SIMOPS: PJSM with crane crew. Set
liner hanger skate and liner hanger on
roof of sub with crane.
0.0 0.0
10/12/2023
23:00
10/13/2023
00:00
1.00 SURFAC, WHDBOP NUND P NU HP riser and 18-3/4" BOP stack and
secure
0.0 0.0
10/13/2023
00:00
10/13/2023
00:45
0.75 SURFAC, WHDBOP NUND P Cont Tq studs on HP riser to wellhead.
SIMOPS: Accumulator monthly work
order
0.0 0.0
10/13/2023
00:45
10/13/2023
03:30
2.75 SURFAC, WHDBOP NUND P MU MPD hoses per MDP rep, install
clamps/whipchecks. Obtain RKB's,
install upper riser, pinched air boot,
change out
0.0 0.0
10/13/2023
03:30
10/13/2023
06:00
2.50 SURFAC, WHDBOP RURD P Energize accumulator, flood BOP
stack/Manifold with water, RU test
equip, close blind rams, shell test
250/5000 psi. SIMOPS: Grease
upper/lower IBOPS, RU test fitting to
TD, MU 5-7/8 test JT and put in
mousehole. MU TIW and dart valve to
test sub
0.0 0.0
10/13/2023
06:00
10/13/2023
07:00
1.00 SURFAC, WHDBOP MPDA P Set RCD test plug, conduct shell test,
250/1200 PSI 5 min each. SIMOPS:
Rebuild kill valve #3
0.0 0.0
10/13/2023
07:00
10/13/2023
08:00
1.00 SURFAC, WHDBOP RURD T MU 5-7/8 test Jt to plug, flood all surface
lines, attempt conduct shell test, test Jt
unseated from plug at 1900 psi, bleed
off all pressure, pull test plug to inspect.
0.0 0.0
10/13/2023
08:00
10/13/2023
09:00
1.00 SURFAC, WHDBOP RURD T MU stack wash tool, 2 Jts 5-7/8 DP,
RIH, Tag top of test plug, wash at max
rate w/ H2O until clean. LD Jts and
wash tool
0.0 0.0
10/13/2023
09:00
10/13/2023
09:45
0.75 SURFAC, WHDBOP RURD T RIH w/ test Jt, pull test plug, debris on
top of plug, function RCD clamp,
annular, UPR, Blinds, LPR, blow down
choke and kill lines
0.0 0.0
10/13/2023
09:45
10/13/2023
10:15
0.50 SURFAC, WHDBOP RURD T MU stack wash tool and 2 Jts 5-7/8 DP,
wash stack at max rate watching for
debris at shakers, BD TD and drain
stack
0.0 0.0
10/13/2023
10:15
10/13/2023
11:00
0.75 SURFAC, WHDBOP RURD T FMC rep decision to run new test plug,
dress plug and prep, MU to 5-7/8 test Jt,
set as per FMC rep.
0.0 0.0
10/13/2023
11:00
10/13/2023
12:00
1.00 SURFAC, WHDBOP BOPE P Begin BOP test. Flood all surface lines,
conduct shell test test
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 5/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/13/2023
12:00
10/13/2023
17:00
5.00 SURFAC, WHDBOP BOPE P Perform BOP test with 5-7/8" test JT,
charted. Annular T/ 250/2500 psi, 5 min
ea. Remaining tests 250/5000 psi, 5 min
ea. #1 Annular 250 psi low, 2500 psi
high. #2 Upper VBRs 3-1/2" x 6-5/8";
CMV 1,14, 15, 16; upper IBOP; kill line
valve #3. #3 Lower IBOP; HCR kill;
CMV 10, 13, needle valve above #1. #4
manual kill; CMV 4, 9, 12. #5 CMV 6, 8,
11. #6 CMV 5 & 7,; Dart valve. #7 CMV
2; TIW valve #8 HCR choke valve. #9
Manual choke valve and HCR kill. #10
Lower VBRs 3-1/2" x 6-5/8". #11 Blind /
shear rams; CMV 3,4,6. #12 Manual
choke & super choke to 1500 psi.
Conduct accumulator draw down.
System pressure 3050 psi; manifold
pressure 1500 psi; after closure 1700
psi; 200 psi build with electric pumps in
13 seconds; full pressure attained in 92
seconds. Closing times: annular 14
seconds; UPR 14 seconds; blind/shear
15 seconds; LPR 15 seconds; choke
HCR 1 second; kill HCR 1 second. 10
bottles nitrogen backup 3800 psi avg.
Gas detection system, pit level
indicators and flow alarms tested. Test
witnessed by AOGCC Josh Hunt.
0.0 0.0
10/13/2023
17:00
10/13/2023
18:00
1.00 SURFAC, WHDBOP RURD T Pull test plug, drain BOP, prep to
change lower ram operators, open lower
ram doors, remove VBR's
0.0 0.0
10/13/2023
18:00
10/13/2023
22:30
4.50 SURFAC, WHDBOP RGRP T Change out both lower ram operator
doors as per SOP and mechanic. Install
3-1/2" x 6-5/8" VBR's, power up Koomy
system, function lower pipe rams
0.0 0.0
10/13/2023
22:30
10/14/2023
00:00
1.50 SURFAC, WHDBOP RGRP T Install FMC test plug per SOP, fluid pack
stack with water, test lower VBR/doors
to 250 psi low
0.0 0.0
10/14/2023
00:00
10/14/2023
01:00
1.00 SURFAC, WHDBOP BOPE P Test lower VBR to 5000 psi, 5 min, open
lower VBR, close upper VBR and shell
test 250/5000 psi 5 min ea, charted.
Remove test plug
0.0 0.0
10/14/2023
01:00
10/14/2023
01:30
0.50 SURFAC, WHDBOP RURD P RU and run FMC wear ring per FMC.
12.43" ID, 42" long
0.0 0.0
10/14/2023
01:30
10/14/2023
01:45
0.25 SURFAC, WHDBOP RURD P RD all test equip, LD test Jt, prep for
casing test
0.0 0.0
10/14/2023
01:45
10/14/2023
03:00
1.25 SURFAC, WHDBOP PRTS P PJSM. Fill stack, close blind rams,
perform casing test to 2600 psi for 30
min charted.
0.0 0.0
10/14/2023
03:00
10/14/2023
06:00
3.00 SURFAC, DRILLOUT BHAH P PJSM. MU 12.25" Int 1 BHA as per SLB
DD. Found damage to Powerdrive box,
break bit and changeout PD. MU 12.25
bit. MU BHA to 128' per DD/MWD
0.0 128.0
10/14/2023
06:00
10/14/2023
07:30
1.50 SURFAC, DRILLOUT TRIP P RIH F/ 128' T/ 2,360' MD. Monitor
displacement on TT. 115K SOW
128.0 2,360.0
10/14/2023
07:30
10/14/2023
08:15
0.75 SURFAC, DRILLOUT REAM P Wash/Ream F/ 2,360' to 2,539' MD. 700
GPM, 660 PSI. 40 RPM, 4K TQ, 60%
FO, 142K RTW
2,360.0 2,539.0
10/14/2023
08:15
10/14/2023
09:30
1.25 SURFAC, DRILLOUT DRLG P Tag FC at 2,539', Drill FC F/2,539' to
2,542' MD, ream 3X's. 700 GPM, 680
PSI, 40 RPM, 6K TQ, 5-12K WOB, 44%
FO, 10.37 ECD
2,539.0 2,542.0
10/14/2023
09:30
10/14/2023
10:45
1.25 SURFAC, DRILLOUT DRLG P Drill cement F/ 2,542' to 2,628' MD. 700
GPM, 810 PSI, 60 RPM, 4K TQ, 1K
WOB, 57% FO
2,542.0 2,628.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 6/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/14/2023
10:45
10/14/2023
11:30
0.75 SURFAC, DRILLOUT DRLG P Tag top shoe at 2,628'. Drill shoe and
cleanout rathole
2,628.0 2,637.0
10/14/2023
11:30
10/14/2023
12:00
0.50 SURFAC, DRILLOUT DDRL P Drill 12-1/4" Int 1 F/ 2,637' to 2,657' MD.
900 GPM, 1080 PSI, 80 RPM, 11K TQ,
10K WOB, 59% FO, 10.48 ECD, 152K
PUW, 132K SOW, 141K RTW
2,637.0 2,657.0
10/14/2023
12:00
10/14/2023
12:15
0.25 SURFAC, DRILLOUT TRIP P Pull into casing for FIT F/ 2,657' to
2,542' MD. 151K PUW
2,657.0 2,542.0
10/14/2023
12:15
10/14/2023
13:00
0.75 SURFAC, DRILLOUT CIRC P Circ/Recip condition mud for FIT F/
2,542' to 2,480' MD. 800 GPM, 850 PSI,
40 RPM, 4K TQ, 50% FO, 10.5 ECD.
Pumped 4200 stks total. 10.0 MW in
and out.
2,542.0 2,542.0
10/14/2023
13:00
10/14/2023
13:30
0.50 SURFAC, DRILLOUT RURD P Blow down TD, RU for FIT test, flood
lines
2,542.0 2,542.0
10/14/2023
13:30
10/14/2023
14:15
0.75 SURFAC, DRILLOUT FIT P Perform FIT/LOT. Pumped 23 stks with
10.0+ ppg mud, 1094 PSI, observed
break over, shut down, monitor shut in
pressure. 18.7 ppg EMW leak off.
2,542.0 2,542.0
10/14/2023
14:15
10/14/2023
14:30
0.25 SURFAC, DRILLOUT RURD P Bleed off pressure, RD lines, clean and
clear floor.
2,542.0 2,542.0
10/14/2023
14:30
10/14/2023
15:45
1.25 INTRM1, DRILL CIRC P Ream to bottom F/ 2,542' to 2,657' MD.
900 GPM, 860 PSI, 100 RPM, 8K TQ,
64% FO, 10.69 ECD. PJSM with crew
on displacement
2,542.0 2,657.0
10/14/2023
15:45
10/14/2023
16:15
0.50 INTRM1, DRILL DISP P Displace well over to 10.8 ppg FWP as
per mud engineer. 800 GPM, 700 PSI,
100 RPM, 4K TQ, 61% FO. 3200 stks
total
2,657.0 2,657.0
10/14/2023
16:15
10/14/2023
18:00
1.75 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
2,657'-2,818' MD, 2,526' TVD. Pumped
bit balling sweeps every 4th stand.
1200 gpm; 1492 psi, 150 rpm, 5K TQ,
5K WOB, 11.13 ECD
ADT 1.57, BIT 1.78, JARS 10.92 hrs
2,657.0 2,818.0
10/14/2023
18:00
10/15/2023
00:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
2,818' to 3,376' MD, 2,802' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1200 GPM, 1580 PSI, 72% FO, 150
RPM, 6K TQ on, 4K TQ off, 5K WOB,
11.11 ECD, 15 units max gas
ADT=4.48, Bit Hrs=6.26, Jar hrs=15.40
2,818.0 3,376.0
10/15/2023
00:00
10/15/2023
06:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
3,376' to 3,920' MD, 2,910' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 2058 PSI, 78% FO, 170
RPM, 7K TQ on, 4K TQ off, 8K WOB,
11.5 ECD, 19 units max gas
143K PUW, 140K SOW, 141K RTW
ADT=4.41, Bit Hrs=10.67, Jar hrs=19.81
3,376.0 3,920.0
10/15/2023
06:00
10/15/2023
12:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
3,920' to 4,488' MD, 2,999' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 2270 PSI, 75% FO, 170
RPM, 9K TQ on, 5K TQ off, 8K WOB,
11.54 ECD, 6 units max gas
148K PUW, 138K SOW, 140K RTW
ADT=4.53, Bit Hrs=15.20, Jar hrs=24.34
3,920.0 4,488.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 7/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/15/2023
12:00
10/15/2023
18:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
4,488' to 5,073' MD, 3,070' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 2444 PSI, 76% FO, 170
RPM, 8K TQ on, 2K TQ off, 6K WOB,
11.62 ECD, 20 units max gas
153K PUW, 138K SOW, 142K RTW
ADT=4.33, Bit Hrs=19.52, Jar hrs=28.66
4,488.0 5,073.0
10/15/2023
18:00
10/15/2023
19:00
1.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
5,073' to 5,136' MD, 3,084' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 2565 PSI, 76% FO, 170
RPM, 7K TQ on, 4K TQ off, 5K WOB,
11.69 ECD, 15 units max gas
153K PUW, 138K SOW, 142K RTW
ADT=.73, Bit Hrs=20.25, Jar hrs=29.39
5,073.0 5,136.0
10/15/2023
19:00
10/15/2023
19:30
0.50 INTRM1, DRILL SVRG P Lubricate rig, grease TD,Blocks, IBOPs,
tighten shot pin
5,136.0 5,136.0
10/15/2023
19:30
10/16/2023
00:00
4.50 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
5,136' to 5,600' MD, 3,149' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 2716 PSI, 77% FO, 170
RPM, 10K TQ on, 6K TQ off, 6K WOB,
11.62 ECD, 10 units max gas
153K PUW, 136K SOW, 139K RTW
ADT=3.58, Bit Hrs=23.83, Jar hrs=32.97
5,136.0 5,600.0
10/16/2023
00:00
10/16/2023
06:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
5,600' to 6,176' MD, 3,226' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 2884 PSI, 75% FO, 170
RPM, 10K TQ on, 5K TQ off, 6K WOB,
11.72 ECD, 17 units max gas
155K PUW, 140K SOW, 144K RTW
ADT=4.48, Bit Hrs=33.24, Jar hrs=37.45
5,600.0 6,176.0
10/16/2023
06:00
10/16/2023
12:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
6,176' to 6,793' MD, 3,226' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 3061 PSI, 72% FO, 170
RPM, 11K TQ on, 5K TQ off, 7K WOB,
11.77 ECD, 27 units max gas
163K PUW, 141K SOW, 141K RTW
ADT=4.93, Bit Hrs=33.24, Jar hrs=42.38
6,176.0 6,793.0
10/16/2023
12:00
10/16/2023
18:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
6,793' to 7,375' MD, 3,401' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 3140 PSI, 72% FO, 170
RPM, 12K TQ on, 4K TQ off, 8K WOB,
11.76 ECD, 26 units max gas
167K PUW, 145K SOW, 152K RTW
ADT=4.73, Bit Hrs=37.97, Jar hrs=47.11
6,793.0 7,375.0
10/16/2023
18:00
10/16/2023
23:45
5.75 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section from
7,375' to 7,827' MD, 3,465' TVD. Obtain
T&D every 5th std. Pumped bit balling
sweeps every 4th stand.
1300 GPM, 3393 PSI, 82% FO, 170
RPM, 13K TQ on, 9K TQ off, 9K WOB,
11.90 ECD, 70 units max gas
169K PUW, 143K SOW, 148K RTW
ADT=4.05, Bit Hrs=42.02, Jar hrs=51.16
7,375.0 7,827.0
10/16/2023
23:45
10/17/2023
00:00
0.25 INTRM1, DRILL SVRG P Wash pipe packing leaking, Pull off
bottom prep to change out.
7,827.0 7,760.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 8/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/17/2023
00:00
10/17/2023
00:30
0.50 INTRM1, DRILL SVRG P CO wash pipe and inspect TD grabber
dies
7,760.0 7,760.0
10/17/2023
00:30
10/17/2023
01:00
0.50 INTRM1, DRILL RGRP T CO wash pipe and grabber dies, PT
wash pipe to 5K psi
7,760.0 7,760.0
10/17/2023
01:00
10/17/2023
01:15
0.25 INTRM1, DRILL REAM P Ream to bottom, 7,760' to 7,827'. 1300
GPM, 3450 PSI, 170 RPM, 6K TQ
7,760.0 7,827.0
10/17/2023
01:15
10/17/2023
01:45
0.50 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section to
TD from 7,827' to 7,845' MD, 3,468'
TVD. Obtain T&D every 5th std.
Pumped bit balling sweeps every 4th
stand.
1300 GPM, 3420 PSI, 80% FO, 170
RPM, 14K TQ on, 8K TQ off, 10K WOB,
11.90 ECD, 70 units max gas
169K PUW, 143K SOW, 148K RTW
ADT=.42, Bit Hrs=42.44, Jar hrs=51.58
7,827.0 7,845.0
10/17/2023
01:45
10/17/2023
03:15
1.50 INTRM1, TRIPCAS CIRC P Circulate and condition mud, w/ rot and
recip F/ 7,842' to 7,770' MD. Perform
550 bbl dilution and increase lubes to
3%, 1300 GPM, 3000 PSI, 79% FO, 120
RPM, 6K TQ, 11.8 ECD
7,845.0 7,845.0
10/17/2023
03:15
10/17/2023
04:30
1.25 INTRM1, TRIPCAS OWFF P Flow check 30 min static, prep floor for
BROOH
7,845.0 7,845.0
10/17/2023
04:30
10/17/2023
06:00
1.50 INTRM1, TRIPCAS BKRM P BROOH w/ NOVOS, F/ 7,845' to 7,452',
3,468' TVD. Monitor hole fill on active to
maintain mud, 1100 GPM, 2300 PSI,
65% FO, 120 RPM, 9K TQ, 11.6 ECD.
169K PUW, 143K SOW, 148K RTW
7,845.0 7,452.0
10/17/2023
06:00
10/17/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH w/ NOVOS, F/ 7,452' to 5,323',
3,110' TVD. Monitor hole fill on active to
maintain mud, 1300 GPM, 2738 PSI,
65% FO, 120 RPM, 7K TQ, 11.51 ECD.
151K PUW, 139K SOW, 138K RTW.
Pump 50 bbl LCM pill around as needed
7,452.0 5,323.0
10/17/2023
12:00
10/17/2023
18:00
6.00 INTRM1, TRIPCAS BKRM P BROOH w/ NOVOS, F/ 5,323' to 2,900',
2,578' TVD. Monitor hole fill on active to
maintain mud, 1300 GPM, 2738 PSI,
65% FO, 120 RPM, 7K TQ, 11.51 ECD.
151K PUW, 139K SOW, 138K RTW.
Pump 50 bbl LCM pill around as needed
5,323.0 2,900.0
10/17/2023
18:00
10/17/2023
19:00
1.00 INTRM1, TRIPCAS BKRM P BROOH w/ NOVOS, F/ 2,900' to 2,571'.
Monitor hole fill on active to maintain
mud, 1300 GPM, 2337 PSI, 54% FO,
120 RPM, 5K TQ, 11.44 ECD. Observed
pressure increase and pushing mud
away.
2,900.0 2,571.0
10/17/2023
19:00
10/17/2023
19:30
0.50 INTRM1, TRIPCAS REAM T Ream in hole to get BHA below possible
pack-off, F/ 2,571' to 2,775' MD.
Reduced flow rate to reduce losses. 600
GPM, 700 PSI, 60 RPM, 42% FO, 12.0
ECD
2,571.0 2,775.0
10/17/2023
19:30
10/17/2023
22:00
2.50 INTRM1, TRIPCAS CIRC T Observed return flow decrease, packed
off pitcher nipple/drip pan/flowline with
clay. Shut down pumps, bleed off
pressure, break up clay to establish flow
path to pits, clean drip dran, drains,
BOP deck, cellar, slowly increase pump
rate to 600 GPM, 10.9 ECD w/ slowly
BR F, 2,775' to 2,727', hole unloading
clay,
2,775.0 2,727.0
10/17/2023
22:00
10/18/2023
00:00
2.00 INTRM1, TRIPCAS BKRM P BROOH w/ NOVOS, F/ 2,727' to 2,560'.
Staging up flow rate and RPM w/
monitoring ECD. 1300 GPM, 2050 PSI,
75% FO, 100 RPM, 4K TQ, 10.9 ECD.
2,727.0 2,560.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 9/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/18/2023
00:00
10/18/2023
03:30
3.50 INTRM1, TRIPCAS BKRM P BROOH from 2,560' MD to 1,800' MD
monitoring ECD's, pressure and torque.
GPM=1300 PSI=1920 RPM=100
TQ=4K F/O=75 ECD=11.10 PPG
2,560.0 1,800.0
10/18/2023
03:30
10/18/2023
03:45
0.25 INTRM1, TRIPCAS OWFF P OWFF, blow down top drive. 1,800.0 1,800.0
10/18/2023
03:45
10/18/2023
04:45
1.00 INTRM1, TRIPCAS TRIP P POOH on elevators racking back 5-7/8"
DP from 1,800' MD to 409' MD. PUW =
120K. Monitoring hole fill via the trip
tank.
1,800.0 409.0
10/18/2023
04:45
10/18/2023
05:00
0.25 INTRM1, TRIPCAS OWFF P OWFF. PJSM for laying down
intermediate 1 BHA.
409.0 409.0
10/18/2023
05:00
10/18/2023
08:30
3.50 INTRM1, TRIPCAS BHAH P Lay down intermediate 1 BHA. Clean
and inspect BHA, gauge bit and
stabilizers. Clean and clear rig floor.
Make up stack wash tool and 2 joints of
drill pipe. Wash at max. rate, function
annular, upper VBR's, blinds and lower
VBR's.
409.0 0.0
10/18/2023
08:30
10/18/2023
09:30
1.00 INTRM1, CASING WWWH P Drain stack, close blind rams, power
down koomey, change upper VBR's to 9
-5/8" solid body rams. SIMOPS prepare
test joint and mobilize casing running
equipment.
0.0 0.0
10/18/2023
09:30
10/18/2023
10:15
0.75 INTRM1, CASING RURD P Pull wear ring and set test plug with 9-
5/8" test joint. Flood all surface lines and
stack with water. Prepare for 9-5/8"
rams test.
0.0 0.0
10/18/2023
10:15
10/18/2023
10:45
0.50 INTRM1, CASING BOPE P Test upper 9-5/8" solid body rams, 250
psi / 3,850 psi for 5 min.
0.0 0.0
10/18/2023
10:45
10/18/2023
11:15
0.50 INTRM1, CASING MPSP P Pull test plug and drain water from the
stack. Blow down kill line, lay down test
joint and pups.
0.0 0.0
10/18/2023
11:15
10/18/2023
13:00
1.75 INTRM1, CASING RURD P Rig up casing equipment. PJSM for 9-
5/8" intermediate 1 casing run.
0.0 0.0
10/18/2023
13:00
10/18/2023
18:00
5.00 INTRM1, CASING PUTB P PU and MU intermediate 1 casing shoe
track, check floats and Bakerlok to pin of
joint #4. Run in hole with 9-5/8", 47#,
T95, HYD 563 casing to 2,600' MD
filling on the fly with volant and topping
off every 20 joints.
0.0 2,600.0
10/18/2023
18:00
10/19/2023
00:00
6.00 INTRM1, CASING PUTB P Continue RIH with 9-5/8" 47#, T95, HYD
563 intermediate 1 casing from 2,600'
MD to 5,623' MD. Torque casing to 16k
ft-lbs, fill on the fly with the volant, top
off every 10 joints monitoring
displacement. SOW = 171k. Gathered
T&D at surface casing shoe PUW=167k
SOW=167k RTW=164k TQ=2.5k.
2,600.0 5,623.0
10/19/2023
00:00
10/19/2023
03:00
3.00 INTRM1, CASING PUTB P RIH from 5,623' MD to 6,668' MD with 9-
5/8" 47#, T95, HYD 563 casing per tally.
Torque to 16k ft-lbs, filling on the fly with
the volant topping off every 10 joints.
SOW=171k
5,623.0 6,668.0
10/19/2023
03:00
10/19/2023
06:00
3.00 INTRM1, CASING CIRC P Circulate bottoms up staging up flow
rate to mitigate losses. RPM=15
Torque=9k ft-lbs.
6,668.0 6,668.0
10/19/2023
06:00
10/19/2023
10:30
4.50 INTRM1, CASING CIRC P Circulate and reciprocate from 6,657'
MD to 6,700' MD SPM=9, PSI=131,
RPM=25, Torque=12k ft-lbs, Flow
out=2%, RW=199k
6,668.0 6,700.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 10/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/19/2023
10:30
10/19/2023
12:00
1.50 INTRM1, CASING PUTB P RIH from 6,700' MD to 6,840' MD with 9-
5/8" 47#, T95, HYD 563 casing. Torque
casing to 16k ft-lbs., wash and ream at 1
BPM, PSI=146, RPM=15, Torque=8k ft-
lbs.
6,700.0 6,840.0
10/19/2023
12:00
10/19/2023
14:00
2.00 INTRM1, CASING PUTB P RIH from 6,840' MD to 7,001' with 9-
5/8", 47#, T95, HYD 563 casing. Torque
casing to 16k ft-lbs, wash and ream at
0.5 BPM, PSI=120, SOW=201k
6,840.0 7,001.0
10/19/2023
14:00
10/19/2023
16:00
2.00 INTRM1, CASING PUTB P RIH from 7,001' MD to 7,845' with 9-
5/8", 47#, T95, HYD 563 casing. Torque
casing to 16k ft-lbs.
7,001.0 7,845.0
10/19/2023
16:00
10/19/2023
21:00
5.00 INTRM1, CASING PUTB P Circulate and reciprocate from 7,811'
MD to 7,843' MD at 1 BPM, PSI=160,
RPM=15, Torque=9k ft-lbs. RW=204k.
Attempted to stage up rate and
encountered losses at 2.5 BPM.
7,845.0 7,845.0
10/19/2023
21:00
10/19/2023
22:30
1.50 INTRM1, CASING PUTB P Make up 9-5/8" hanger and landing
joint. RIH and land 9-5/8" casing at
7,839' MD.
7,845.0 7,845.0
10/19/2023
22:30
10/20/2023
00:00
1.50 INTRM1, CEMENT RURD P Blow down top drive, rig up cement
hose and 2" hard iron. Pressure test
suface equipment to 4,000 psi. PJSM
for cement job.
7,845.0 7,845.0
10/20/2023
00:00
10/20/2023
04:30
4.50 INTRM1, CEMENT CMNT P Pressure tested cement lines to 4,000
psi. Pumped 75.2 bbls of 12.0 ppg Mud
Push II, dropped bottom plug, pumped
166 bbls of 15.8 ppg tail cement, 20 bbls
of cement contained cemnet, dropped
top plug and pumped 20 bbls of water.
Swapped to rig and displaced with 10.8
ppg FWP at 5 BPM, reduced rate to 2.5
BPM at 3,200 strokes. Bottom plug
landed at 3,259 strokes, plug burst
PSI=356. Continue displacing with 10.8
ppg FWP at 2.5 BPM until top plug
bump at 4,624 strokes, final circulating
pressure of 321 psi. Pressured up to
821 psi and held for 5 min.
7,845.0 0.0
10/20/2023
04:30
10/20/2023
05:30
1.00 INTRM1, CEMENT PRTS P Perform casing pressure test to 3,850
psi and held for 30 min. Pumped 9.7
bbls and bled back 9.5 bbls. Good test.
0.0 0.0
10/20/2023
05:30
10/20/2023
08:00
2.50 INTRM1, CEMENT RURD P Rig down cement line and hard iron.
Back out landing joint and lay down. Rig
down casing equipment. Clear rig floor
and clean cement valves.
0.0 0.0
10/20/2023
08:00
10/20/2023
10:00
2.00 INTRM1, WHDBOP WWSP P Pick up stand of 5-7/8" drill pipe and
make up FMC packoff running tool. Run
in hole with packoff and set down 10k
lbs. Test packoff to 5,000 psi for 10 min.
CPAI witness.
0.0 0.0
10/20/2023
10:00
10/20/2023
12:30
2.50 INTRM1, WHDBOP RURD P Make up stack washer to stand of 5-7/8"
drill pipe. Wash stack @ 1400 gpm and
15 rpm. Blow down top drive.
0.0 0.0
10/20/2023
12:30
10/20/2023
14:00
1.50 INTRM1, WHDBOP RURD T Steam and hammer on tool joint.
Attempt to break out stand from top
drive. Connection broke at saver sub.
Remove lock rings. Change out grabber
dies.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 11/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/20/2023
14:00
10/20/2023
16:00
2.00 INTRM1, WHDBOP RURD P Lay down top single of stand #1 with
saver sub attached to it. Install new 5-
7/8" saver sub. Torque lower lock ring
bolts to spec check torque on upper lock
ring. Wire tie all bolts. Make up new
single joint of 5-7/8" drill pipe on top of
stand #1. Pull out of hole and remove
stack washer and rack back stand in the
derrick.
0.0 0.0
10/20/2023
16:00
10/20/2023
16:30
0.50 INTRM1, WHDBOP RURD P Drain mud out of the stack. Fill and flush
with water and drain below the blind
rams. Shut blind rams and bleed off
accumulator.
0.0 0.0
10/20/2023
16:30
10/20/2023
18:00
1.50 INTRM1, WHDBOP RURD P Change upper 9-5/8" pipe rams to 3-1/2"
x 6-5/8" VBR's.
0.0 0.0
10/20/2023
18:00
10/20/2023
19:30
1.50 INTRM1, WHDBOP RURD P Make up pups to 4-1/2" test joint, make
up test plug, run in hole and set.
0.0 0.0
10/20/2023
19:30
10/20/2023
22:00
2.50 INTRM1, WHDBOP RURD P Fill stack with water. Purge all lines of
air. PJSM. Shell test BOP to 3,500 psi,
purge air. Test upper and lower VBR's to
3,500 psi.
0.0 0.0
10/20/2023
22:00
10/21/2023
00:00
2.00 INTRM1, WHDBOP BOPE P Perform BOP test with 4-1/2" test joint.
Annular to 250 psi low, 2,500 psi high
for 5 minutes each. Remaining tests to
250 psi low, 3,850 psi high for 5
minutes. 1. annular with 4-1/2" test joint.
2. upper 3-1/2" x 6-5/8" VBR's with 4-
1/2" test joint. CMW #1, 14, 15, 16, kill
line valve #3, upper IBOP. 3. CMV
#10,13, needle valve above #1, HCR
kill, lower IBOP. 4. CMV #4, 9, 12,
manual kill and 5-7/8" TIW. 5. CMV #6,
8, 11, and 5-7/8" dart. 6. CMV #5, #7
and 4-1/2" TIW.
0.0 0.0
10/21/2023
00:00
10/21/2023
04:00
4.00 INTRM1, WHDBOP BOPE P 10. Lower 3-1/2" x 6-5/8" VBR's with 4-
1/2" test joint. 11. Blind shears. CMV #3,
4 and 6. 12. Manual and super choke to
1,500 psi. 13. Upper 3-1/2" x 6-5/8"
VBR's with 5-7/8" test joint. 14. Lower 3-
1/2" x 6-5/8" VBR's with 5-7/8" test joint.
Conduct accumulator drawdown
ACC=3,100 psi, Manifold=1,490 psi
after all functions on bottles, 13 seconds
for 200 psi. Build with 2 electric pumps,
96 seconds to full system pressure with
2 electric and air pumps, closing times:
annular = 24 seconds, UPR = 16
seconds, blind / shears = 17 seconds,
LPR = 16 seconds, Choke HCR = 1
second, Kill HCR = 1 second, test PVT
gain / loss and flow out alarms, 10 bottle
nitrogen backup average = 3,750 psi.
Test LEL and H2S alarms. AOGCC
REP: Austin McLeod waived witness on
10/18/2023.
0.0 0.0
10/21/2023
04:00
10/21/2023
06:00
2.00 INTRM1, WHDBOP RURD P Blow down testing equipment, pull test
plug and install wear ring. Lay down test
joint and running tool. SIMOPS:
Function all four M/P pop offs, adjust all
4 M/P pulsation dampeners.
0.0 0.0
10/21/2023
06:00
10/21/2023
07:45
1.75 INTRM1, WHDBOP RURD P Fill stack with mud. Prepare to Pick up
the intermediate 1 BHA. Lubricate rig.
0.0 0.0
10/21/2023
07:45
10/21/2023
09:30
1.75 INTRM1, DRILLOUT BHAH P PU and MU intermediate 1 BHA to 117'
MD. POOH to 52' MD. PJSM, then
install sources in BHA.
0.0 117.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 12/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/21/2023
09:30
10/21/2023
11:30
2.00 INTRM1, DRILLOUT BHAH P Continue making up BHA from 117' MD
to 382' MD. SIMOPS: Test gas alarms
and LRS freeze protect. Freeze
protected 13-3/8" x 9-5/8" annulus with
89 bbls of diesel at 2 BPM, 603-756 psi.
Shut in pressure = 700 psi.
117.0 382.0
10/21/2023
11:30
10/21/2023
15:00
3.50 INTRM1, DRILLOUT PULD P Single in hole on 4-1/2" DP to 2,265 '
MD. PUW = 122K, SOW = 122K. Fill
pipe and shallow hole test tools at 500
gpm / 1,230 psi.
382.0 2,265.0
10/21/2023
15:00
10/21/2023
17:30
2.50 INTRM1, DRILLOUT PULD P Continue singling in the hole on 4-1/2"
drill pipe out of the pipe shed to 4,150'
MD.
2,265.0 4,150.0
10/21/2023
17:30
10/21/2023
18:00
0.50 INTRM1, DRILLOUT RURD P Make up crossover to the top drive, fill
pipe, lay down crossover and blow down
the top drive.
4,150.0 4,150.0
10/21/2023
18:00
10/21/2023
19:00
1.00 INTRM1, DRILLOUT PULD P Continue singling in the hole on 4-1/2"
DP to 5,191' MD
4,150.0 5,191.0
10/21/2023
19:00
10/21/2023
21:00
2.00 INTRM1, DRILLOUT TRIP P Swap to 5-7/8" drill pipe out of the
derrick and run in the hole to 7,615' MD
filling every 2,000' monitoring the hole
via the trip tank.
5,191.0 7,615.0
10/21/2023
21:00
10/21/2023
21:30
0.50 INTRM1, DRILLOUT WASH P Wash down from 7,615' MD to 7,754'
MD, 450gpm, 1,430 psi, PUW = 150k.
Tag top of cement at 7,754' MD.
7,615.0 7,754.0
10/21/2023
21:30
10/22/2023
00:00
2.50 INTRM1, DRILLOUT REAM P Ream plugs and float collar from 7,754'
MD to 7,756' MD. Ream cement from
7,756' MD to 7,768' MD with 550 gpm,
1,969 psi, 40% flow out, 60 rpm, 10k ft-
lbs torque and PUW=150k.
7,754.0 7,768.0
10/22/2023
00:00
10/22/2023
01:00
1.00 INTRM1, DRILLOUT DRLG P Ream cement from 7,768' MD to 7,839'
MD, 550 gpm, 1,969 psi, flow out = 40,
80 rpm, 4k ft-lbs torque and PUW =
150k.
7,768.0 7,839.0
10/22/2023
01:00
10/22/2023
04:00
3.00 INTRM1, DRILLOUT DRLG P Ream shoe from 7,839' MD to 7,842'
MD, 550 gpm, 1960 psi, 80 rpm, WOB =
4k, 10k-13k ft-lbs torque
7,839.0 7,842.0
10/22/2023
04:00
10/22/2023
04:15
0.25 INTRM1, DRILLOUT DRLG P Ream down through 9-5/8" shoe three
times from 7,845' MD to 7,830' MD, 550
gpm, 2020 psi, 80 rpm, 7k ft-lbs torque
and WOB = 1k.
7,842.0 7,845.0
10/22/2023
04:15
10/22/2023
04:30
0.25 INTRM1, DRILLOUT DDRL P Drill 20' of new formation from 7,845'
MD to 7,865' MD. 550 gpm, 2032 psi, 80
rpm, 9k ft-lbs torque, WOB = 2k and
flow out = 40.
7,845.0 7,865.0
10/22/2023
04:30
10/22/2023
05:00
0.50 INTRM1, DRILLOUT BKRM P BROOH from 7,865' MD to 7,790' MD.
550 gpm, 2032 psi, 80 rpm, 9k ft-lbs
torque, WOB = 2k and flow out = 40.
7,865.0 7,790.0
10/22/2023
05:00
10/22/2023
06:00
1.00 INTRM1, DRILLOUT RURD P Blow down top drive. Make up 5' pup for
spaceout. Rig up head pin and pumping
equipment for FIT. Fluid pack drill string
and kill line.
7,790.0 7,790.0
10/22/2023
06:00
10/22/2023
07:00
1.00 INTRM1, DRILLOUT FIT P Perform FIT with 10.7 ppg FWP with
598 psi to 14.0 ppg EMW at 2 SPM, 1.1
bbls pumped and 1 bbl returned. Shut in
and hold for 10 minutes.
7,790.0 7,790.0
10/22/2023
07:00
10/22/2023
07:45
0.75 INTRM1, DRILLOUT RURD P Rig down test equpment. Blow down
choke and kill lines. Lay down 5' pup.
7,790.0 7,790.0
10/22/2023
07:45
10/22/2023
08:15
0.50 INTRM1, DRILLOUT CIRC P Circulate bottoms up at 600 gpm, 2225
psi to retrieve FIT data from Ecoscope.
7,790.0 7,790.0
10/22/2023
08:15
10/22/2023
09:15
1.00 INTRM2, DRILL MPDA P PJSM. Install 5-7/8" MPD bearing. 7,790.0 7,790.0
10/22/2023
09:15
10/22/2023
09:45
0.50 INTRM2, DRILL MPDA P Pressure test MPD lines. 7,790.0 7,790.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 13/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/22/2023
09:45
10/22/2023
11:15
1.50 INTRM2, DRILL DISP P PJSM. Displace well from 10.8 ppg
FWP to 9.0 ppg FWP at 604 gpm, 2000
psi, 60 rpm and 9-12k ft-lbs torque. 60
bbls of interface.
7,790.0 7,790.0
10/22/2023
11:15
10/22/2023
12:00
0.75 INTRM2, DRILL REAM P Obtain SPR's. Wash and ream down
from 7,790' MD to7,865' MD at 700
gpm, 2540 psi, 60 rpm and 9-12k ft-lbs
torque.
7,790.0 7,865.0
10/22/2023
12:00
10/22/2023
14:15
2.25 INTRM2, DRILL DDRL P Drill 8-1/2" intermediate 2 from 7,865'
MD to 7,992' MD / 3,490' TVD. 700
gpm, 2554 psi, 100 rpm, 7-10k ft-lbs on
bottom, 5-8k ft-lbs torque off bottom, 10-
11k lbs WOB, 11.91 ECD.
PUW / SOW / RTW = 145k / 120k / 137k
7,865.0 7,992.0
10/22/2023
14:15
10/22/2023
15:00
0.75 INTRM2, DRILL CIRC P Pull up to 7,974' MD. Obtain base
parameters. Drop 1-1/4" steel ball and
pump down at 250 gpm, 880 psi, 30
rpm, 1-3k ft-lbs torque. Slowed to 100
gpm, 700 psi at 300 strokes pumped.
Ball on seat at 596 strokes, reamer
indexed open. Stage flow rate up to 700
gpm, 2160 psi, 60 rpm, 3-6k ft-lbs
torque while digging a shelf with reamer
from 7,982' MD to 7,974' MD. Stop
rotary and set down 5k lbs at 7,982' MD
and pull over 5k lbs at 7,974' MD.
7,992.0 7,974.0
10/22/2023
15:00
10/22/2023
15:15
0.25 INTRM2, DRILL DDRL P Ream down from 7,982' MD to 7,992'
MD at 700 gpm, 2160 psi, 60 rpm and 3-
6k ft-lbs torque.
7,974.0 7,992.0
10/22/2023
15:15
10/22/2023
18:00
2.75 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2 with
XS2 reamer from 7,992' MD to 8,210'
MD / 3,520' TVD. MPD holding 12.0 ppg
EMW at the shoe while drilling and on
connections. 700 gpm, 2261 psi, 150
rpm, 8-10k ft-lbs on bottom torque, 7-9k
ft-lbs off bottom torque, 14k lbs WOB,
12.09 ppg ECD, PUW / SOW / RTW =
155k / 125k / 140k ADT = 3.1 / Bit hrs =
3.72 / Jar hrs. = 55.3
7,992.0 8,210.0
10/22/2023
18:00
10/23/2023
00:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2 with
XS2 reamer from 8,210' MD to 8,624'
MD / 3,579' TVD . MPD holding 12.0
ppg EMW at the shoe while driling and
on connections. 750 gpm, 2507 psi, 150
rpm, 13k ft-lbs torque on bottom, 9k ft-
lbs torque off bottom, 14k lbs WOB,
12.13 ppg ECD. Max. Gas = 30. PUW /
SOW / ROT = 160k / 116k / 138k. ADT =
4.71 / BIT hrs. = 8.43 / Jar hrs. = 60.01
8,210.0 8,624.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 14/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/23/2023
00:00
10/23/2023
06:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 8,624' MD
to 9,000' MD / 3,632' TVD. Pumping 40
bbl bit balling sweeps every fourth
stand, torque and drag every fifth stand.
MPD holding 12.0 ppg EMW at the
intermediate 1 shoe. 700 gpm, 2404 psi,
150 rpm, 13k ft-lbs on bottom torque, 8k
ft-lbs off bottom torque, 13k lbs WOB,
12.23 ppg ECD, Max gas = 24.
PUW / SOW / RTW =
162k / 116k / 139k
ADT=4.07 / Bit hrs=12.5 / Jar hrs=64.08
SPR's at 8,715' MD / 3,589' TVD
MW = 9.0 ppg at 02:30
MP1 at 20 SPM-705/435
MP1 at 30 SPM-720/410
MP2 at 20 SPM-712/435
MP2 at 30 SPM-730/410
8,624.0 9,000.0
10/23/2023
06:00
10/23/2023
12:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 9,000' MD
to 9,550' MD / 3,710' TVD. Pumping 40
bbl bit balling sweeps every fourth
stand, torque and drag every fifth stand.
MPD holding 12.0 ppg EMW at the
intermediate 1 shoe. 700 gpm, 2466 psi,
150 rpm, 11k ft-lbs on bottom torque,
7.5k ft-lbs off bottom torque, 10k lbs
WOB, 12.05 ppg ECD, Max gas = 91.
PUW / SOW / RTW =
164k / 121k / 145k.
9,000.0 9,550.0
10/23/2023
12:00
10/23/2023
18:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 9,550' MD
to 10,013' MD / 3,771' TVD. Pumping 40
bbl bit balling sweeps every fourth
stand, torque and drag every fifth stand.
MPD holding 12.0 ppg EMW at the
intermediate 1 shoe. 700 gpm, 2441 psi,
140 rpm, 11k ft-lbs on bottom torque, 8k
ft-lbs off bottom torque, 10.5k lbs WOB,
12.08 ppg ECD, Max gas = 91.
PUW / SOW / RTW =
164k / 121k / 145k.
ADT=4.74 / Bit hrs=21.76 / Jar
hrs=73.34
SPR's at 9,920' MD, 3,764' TVD
MW = 9.0 ppg at 16:28
MP1 at 20 SPM-790/456
MP1 at 30 SPM-825/425
MP2 at 20 SPM-800/454
MP2 at 30 SPM-825/420
9,550.0 10,013.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 15/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/23/2023
18:00
10/24/2023
00:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 10,013'
MD to 10,545' MD / 3,852' TVD.
Pumping 40 bbl bit balling sweeps every
fourth stand, torque and drag every fifth
stand. MPD holding 12.0 ppg EMW at
the intermediate 1 shoe. 700 gpm, 2581
psi, 140 rpm 13k ft-lbs on bottom torque,
8k ft-lbs off bottom torque, 13k lbs
WOB, 12.1 ppg ECD, Max gas = 117.
PUW / SOW / RTW =
169k / 117k / 140k.
ADT=4.52 / Bit hrs=26.28 / Jar
hrs=77.86
10,013.0 10,545.0
10/24/2023
00:00
10/24/2023
06:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 10,545'
MD to 11,034' MD / 3,921' TVD.
Pumping 40 bbl bit balling sweeps every
fourth stand, torque and drag every fifth
stand. MPD holding 12.0 ppg EMW at
the intermediate 1 shoe. 700 gpm, 2581
psi, 140 rpm 13k ft-lbs on bottom torque,
8k ft-lbs off bottom torque, 13k lbs
WOB, 12.1 ppg ECD, Max gas = 117.
PUW / SOW / RTW =
169k / 117k / 140k.
ADT=3.84 / Bit hrs=30.12 / Jar
hrs=81.70
MP1 at 20 SPM-804/455 MP1 at 30
SPM-835/420
MP2 at 20 SPM-820/454 MP2 at 30
SPM-845/418
10,545.0 11,034.0
10/24/2023
06:00
10/24/2023
12:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 11,034'
MD to 11,667' MD / 4,007' TVD.
Pumping 40 bbl bit balling sweeps every
fourth stand, torque and drag every fifth
stand. MPD holding 12.0 ppg EMW at
the intermediate 1 shoe. 700 gpm, 2590
psi, 140 rpm 14k ft-lbs on bottom torque,
8k ft-lbs off bottom torque, 9k lbs WOB,
12.12 ppg ECD, Max gas = 392.
PUW / SOW / RTW =
169k / 117k / 140k.
ADT=4.52 / Bit hrs=26.28 / Jar
hrs=77.86
OA PSI=587
11,034.0 11,667.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 16/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/24/2023
12:00
10/24/2023
18:00
6.00 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 11,667'
MD to 12,267' MD / 4,063' TVD.
Pumping 40 bbl bit balling sweeps every
fourth stand, torque and drag every fifth
stand. MPD holding 12.0 ppg EMW at
the intermediate 1 shoe. 700 gpm, 2530
psi, 140 rpm 14.5k ft-lbs on bottom
torque, 9k ft-lbs off bottom torque, 11k
lbs WOB, 12.01 ppg ECD, Max gas =
300.
PUW / SOW / RTW =
175k / 122k / 151k.
ADT=4.14 / Bit hrs=38.75 / Jar
hrs=90.33
SPR's at 12,144' MD / 4,052' TVD, 9.0
ppg at 14:39
MP1 at 20 SPM-800/453 MP1 at 30
SPM-820/420
MP2 at 20 SPM-810/452 MP2 at 30
SPM-825/419
11,667.0 12,267.0
10/24/2023
18:00
10/24/2023
19:30
1.50 INTRM2, DRILL DDRL P Drill 8-1/2" x 9-1/2" intermediate 2
section with XS2 reamer from 12,267'
MD to 12,390' MD / 4,071' TVD.
Pumping 40 bbl bit balling sweeps every
fourth stand, torque and drag every fifth
stand. MPD holding 12.0 ppg EMW at
the intermediate 1 shoe. 700 gpm, 2563
psi, 140 rpm 13k ft-lbs on bottom torque,
9k ft-lbs off bottom torque, 13k lbs
WOB, 12.01 ppg ECD, Max gas = 70.
PUW / SOW / RTW =
173k / 118k / 152k.
ADT=1.13 / Bit hrs=39.88 / Jar
hrs=91.46
12,267.0 12,390.0
10/24/2023
19:30
10/24/2023
20:30
1.00 INTRM2, TRIPCAS CIRC P Gather baseline parameters with
underreamer open, 100 rpm, 9-12k ft-lbs
torque, 700 gpm, 2515 psi, turbine
RPM=4140. Break off and drop a 1.625"
deactivation ball, kelly up and roll
pumps. Pump rate 250 gpm for the first
650 strokes at 952 psi. Reduce rate to
100 gpm for the remainder strokes at
802 psi. Total strokes for ball on seat
was 1,141 strokes and 2,278 psi to shift
closed. Gather closed parameters 100
rpm, 8 ft-lbs torque, 700 gpm, 2632 psi
and Turbine rpm=4350.
12,390.0 12,390.0
10/24/2023
20:30
10/24/2023
21:45
1.25 INTRM2, TRIPCAS BKRM P CBU while rotating and reciprocating
from 12,390' MD to 12,370' MD keeping
the BHA in the rat hole for half the BU.
Then reciprocate full stand from 12,370'
MD to 12,329' MD. 700 gpm, 2662 psi,
130 rpm, 8k ft-lbs torque, 12.03 ppg
ECD. Gather final Torque and drag and
SPR's.
MP1 at 20 SPM-865/455 MP1 at 30
SPM-905/420
MP2 at 20 SPM-865/455 MP2 at 30
SPM900/420
12,390.0 12,329.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 17/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/24/2023
21:45
10/25/2023
00:00
2.25 INTRM2, TRIPCAS OWFF P MPD open choke. Take backside pump
off, bleed well off and OWFF. Flow
decreasing over time. SIMOPS service
top drive, ST-120 and grease upper-
lower IBOP's.
OA PSI=364
12,329.0 12,329.0
10/25/2023
00:00
10/25/2023
01:30
1.50 INTRM2, TRIPCAS OWFF P Monitored well to static. Observed static
for 30 minutes. SIMOPS greased
blocks, top drive, upper & lower IBOP &
removed hatch covers in floor.
12,329.0 12,329.0
10/25/2023
01:30
10/25/2023
06:00
4.50 INTRM2, TRIPCAS BKRM P Back reamed out of the hole from
12,329'-11,230' MD. Weighted up from
9.0 to 9.2 ppg. Holding an 12.0 EMW at
the shoe.
700 gpm; 2653 psi
130 rpm; Tq 7K
ECD 12.01
RPUW 144K
12,329.0 11,230.0
10/25/2023
06:00
10/25/2023
12:00
6.00 INTRM2, TRIPCAS BKRM P Back reamed out of the hole from
11,230'-9640' MD. Holding an 12.0
EMW at the shoe.
700 gpm; 2610 psi
120 rpm; Tq 9-11K
ECD 12.12
RPUW 146K
11,230.0 9,640.0
10/25/2023
12:00
10/25/2023
18:00
6.00 INTRM2, TRIPCAS BKRM P Back reamed out of the hole from 9640'-
8600' MD. Holding an 12.0 EMW at the
shoe. Observed flow restriction at
10,040' & 8759' MD. Slowed parameters
to 100 rpm & 600 gpm.
600 gpm; 2050 psi
100 rpm; Tq 10K
ECD 11.85
RPUW 136K
9,640.0 8,600.0
10/25/2023
18:00
10/26/2023
00:00
6.00 INTRM2, TRIPCAS BKRM P Back reamed out of the hole from 8600'-
8292' MD. Holding an 12.0 EMW at the
shoe. Continued to observe flow
restrictions. Used varying parameters to
minimize pressure increases & ECD
spikes; 600-650 gpm, 100-140 rpm &
varying pulling speeds.
600 gpm; 2050 psi
140 rpm; Tq 8K
ECD 12.01
RPUW 136K
8,600.0 8,292.0
10/26/2023
00:00
10/26/2023
05:30
5.50 INTRM2, TRIPCAS BKRM P Back reamed out of the hole from 8292'-
8222' MD. Held an 12.0 EMW at the
shoe. Continued to observe flow
restrictions. Used varying parameters to
minimize pressure increases & ECD
spikes; 600-625 gpm, 100-140 rpm &
varied pulling speeds. Observed 6K
overpull at 8222' MD and 125 psi
pressure increase when pulling speed
was reduce to 10 fph.
600 gpm; 2050 psi
140 rpm; Tq 8K
ECD 11.6
RPUW 135K
8,292.0 8,223.0
10/26/2023
05:30
10/26/2023
06:00
0.50 INTRM2, TRIPCAS CIRC T Decision was made to circulate a
bottoms up to clear any debris. Racked
back a stand of drill pipe & circulated
bottoms up from 8223'-8339' MD.
650 gpm; 2230 psi
120 rpm; Tq 7K
8,223.0 8,339.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 18/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/26/2023
06:00
10/26/2023
07:15
1.25 INTRM2, TRIPCAS BKRM T Back reamed out of the hole from 8339'-
8221' MD. Encountered 200 psi
pressure increase at 8222' MD. Worked
string down to 8229' MD and slowed
pump rate to 300 gpm, 934 psi & 50
rpm, Tq 4-8K. Worked back up and saw
50 psi increase with 20K overpull to pull
past 8222' MD.
650 gpm; 2229 psi
120 rpm; Tq 8K
ECD 11.6
RPUW 136K
8,339.0 8,221.0
10/26/2023
07:15
10/26/2023
10:30
3.25 INTRM2, TRIPCAS BKRM P Back reamed out of the hole from 8221'-
7788' MD. Held an 12.0 EMW at the
shoe. Observed 10-18K torque swings
with no pressure increase at 8175' MD.
300 gpm; 934 psi
50 rpm; Tq 4-8K
ECD 11.6
RPUW 136K
8,221.0 7,788.0
10/26/2023
10:30
10/26/2023
11:00
0.50 INTRM2, TRIPCAS CIRC P Circulated bottoms up inside the shoe.
700 gpm; 2487 psi
60 rpm; Tq 5-9K
ECD 11.61
RTW 138K
7,788.0 7,788.0
10/26/2023
11:00
10/26/2023
21:00
10.00 INTRM2, TRIPCAS OWFF P Monitored well for flow. Isolated MPD
system & opened 2" outlet on RCD.
Observed initial flow at 1.24 bph
decreased to .19 bph. Decision made to
weight up mud system from 9.3 to 9.5
ppg.
7,788.0 7,788.0
10/26/2023
21:00
10/26/2023
23:30
2.50 INTRM2, TRIPCAS CIRC P Circulated, weighting up mud system
from 9.3 to 9.5 ppg.
380 gpm; initial 940 psi; finish 950 psi
40 rpm; Tq 4-5K
ECD initial 10.5; finish 10.64
7,788.0 7,788.0
10/26/2023
23:30
10/27/2023
00:00
0.50 INTRM2, TRIPCAS OWFF P Monitored well for flow. Observed
decreasing flow return to the pits.
7,788.0 7,788.0
10/27/2023
00:00
10/27/2023
03:00
3.00 INTRM2, TRIPCAS OWFF P Monitored well for flow. Recorded data
of flow decreasing from .17 bph to .031
bph. Data collected indicated well bore
breathing.
7,788.0 7,788.0
10/27/2023
03:00
10/27/2023
05:00
2.00 INTRM2, TRIPCAS SMPD P Stripped out of the hole from 7788'-
7026' MD. Held 11.0 EMW with MPD.
Dropped 2.875 drift at stand 79. PUW
155K. Started seeing indications of
dragging debris with drill string.
Observed 20K over pull at 7123' MD.
Observed 40K over pull at 7073' MD.
Dropped down and rotated at 5 rpm,
break over torque at 9.5K, free rotate at
4-5K. Decision made to wash & ream
down 2 stands to attempt to wash debris
out.
7,788.0 7,026.0
10/27/2023
05:00
10/27/2023
06:00
1.00 INTRM2, TRIPCAS REAM T Reamed down from 7026'-7232' MD.
700 gpm, 2650 psi
130 rpm, Tq 7K
7,026.0 7,232.0
10/27/2023
06:00
10/27/2023
06:45
0.75 INTRM2, TRIPCAS CIRC T Circulated bottoms up. Recovered
pieces of composite debris & fiber glass
mesh, thought to be from casing float
equipment. Blow down top drive.
700 gpm; 2460 psi
130 rpm; Tq 6-8K
ECD 11.4
RTW 139K
7,232.0 7,139.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 19/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/27/2023
06:45
10/27/2023
08:30
1.75 INTRM2, TRIPCAS SMPD P Stripped out of the hole from 7139'-
5876' MD. Held 11.0 EMW with MPD.
Observed 20K over pull at 5876' MD.
PUW 137K.
7,139.0 5,876.0
10/27/2023
08:30
10/27/2023
09:00
0.50 INTRM2, TRIPCAS SMPD T Stripped in the hole from 5876'-6030'
MD. Held 11.0 EMW with MPD. SOW
106K.
5,876.0 6,030.0
10/27/2023
09:00
10/27/2023
09:30
0.50 INTRM2, TRIPCAS CIRC T Circulated bottoms up to flush up any
debris around the BHA.
700 gpm; 2300 psi
120 rpm; Tq 4-7K
6,030.0 5,933.0
10/27/2023
09:30
10/27/2023
10:30
1.00 INTRM2, TRIPCAS SMPD P Stripped out of the hole from 5933'-
5256' MD. Held 11.0 EMW with MPD.
PUW 130K.
5,933.0 5,256.0
10/27/2023
10:30
10/27/2023
11:30
1.00 INTRM2, TRIPCAS OWFF P Monitored well for flow. Recorded data
of flow decreasing from 3.0 bph to .61
bph. Data collected indicated well bore
breathing.
5,256.0 5,256.0
10/27/2023
11:30
10/27/2023
13:00
1.50 INTRM2, TRIPCAS MPDA P Removed MPD 5-7/8" bearing &
installed 4-1/2" bearing as per MPD
Advisor.
5,256.0 5,256.0
10/27/2023
13:00
10/27/2023
18:15
5.25 INTRM2, TRIPCAS SMPD P Stripped out of the hole from 5256'-475
MD. Held 10.0 EMW with MPD. PUW
110K.
5,256.0 475.0
10/27/2023
18:15
10/27/2023
20:30
2.25 INTRM2, TRIPCAS OWFF P Monitored well for flow. Recorded data
of flow decreasing from .35 bph to .07
bph. Data collected indicated well bore
breathing.
475.0 475.0
10/27/2023
20:30
10/27/2023
21:00
0.50 INTRM2, TRIPCAS MPDA P Removed 4-1/2" MPD bearing as per
Advisor.
475.0 475.0
10/27/2023
21:00
10/27/2023
22:15
1.25 INTRM2, TRIPCAS BHAH P Racked back 5-7/8" HWDP in the
derrick. Laid down JARS & replaced it
with joint of 5-7/8" HWDP. Float
equipment debris was recovered from
JARS.
475.0 189.0
10/27/2023
22:15
10/28/2023
00:00
1.75 INTRM2, TRIPCAS BHAH P Laid down intermediate 2 BHA as per
SLB Directional from 187'-52' MD.
Recovered more float equipment debris
from the bit.
189.0 52.0
10/28/2023
00:00
10/28/2023
00:45
0.75 INTRM2, TRIPCAS BHAH P Finished laying down intermediate 2
BHA as per SLB Directional from 52'
MD.
52.0 0.0
10/28/2023
00:45
10/28/2023
01:15
0.50 INTRM2, TRIPCAS BHAH P Cleared & cleaned rig floor. 0.0 0.0
10/28/2023
01:15
10/28/2023
02:15
1.00 INTRM2, TRIPCAS WWWH P Made up stack wash tool on a stand of 5
-7/8" drill pipe. Washed stack &
wellhead 3 times. Laid down tool &
racked back stand. Blew down top drive.
650 gpm; 25 psi
15-20 rpm
0.0 0.0
10/28/2023
02:15
10/28/2023
03:30
1.25 INTRM2, TRIPCAS RURD P Drained the BOP stack & made up wear
ring tool. Pulled wear ring & installed
test plug per FMC Rep.
0.0 0.0
10/28/2023
03:30
10/28/2023
05:00
1.50 INTRM2, TRIPCAS RURD P Closed blind rams & de-energized
accumulator system. Changed out
upper VBRs to 7-5/8" solid body rams.
0.0 0.0
10/28/2023
05:00
10/28/2023
05:30
0.50 INTRM2, TRIPCAS RURD P Energized accumulator system. Opened
blinds. Installed 7-5/8" test joint. Filled
stack with water & flooded lines. Rigged
up test equipment.
0.0 0.0
10/28/2023
05:30
10/28/2023
06:00
0.50 INTRM2, TRIPCAS BOPE P Pressured tested upper rams with 7-5/8"
test joint to 250 & 3850 psi for 5 minutes
each, charted. Witness waived by
AOGCC Rep Kam StJohn.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 20/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/28/2023
06:00
10/28/2023
07:15
1.25 INTRM2, TRIPCAS RURD P Rigged down test equipment. Pulled test
joint. Removed test plug & installed
wear ring. Wear ring OD 13.42"; ID
8.66"; length 12.5".
0.0 0.0
10/28/2023
07:15
10/28/2023
08:00
0.75 INTRM2, TRIPCAS RURD P Laid down test joint and 2 pup joints. 0.0 0.0
10/28/2023
08:00
10/28/2023
09:30
1.50 INTRM2, TRIPCAS RGRP T Drained riser to annular. Closed blind
rams. Changed out upper air boot on
the riser & installed spare.
0.0 0.0
10/28/2023
09:30
10/28/2023
11:00
1.50 INTRM2, CASING RURD P Rigged up to run 7-5/8" liner. Rigged up
double stack tongs. Installed bales &
elevators. Rigged up fill up line.
0.0 0.0
10/28/2023
11:00
10/28/2023
12:00
1.00 INTRM2, CASING PUTB P Made up 7-5/8", 29.7 #, L80, Hyd 523
liner shoe track to 252' MD.
Connections made up with BakerLok &
torque to 12K.Checked floats, good.
0.0 252.0
10/28/2023
12:00
10/28/2023
18:00
6.00 INTRM2, CASING PUTB P Run 7-5/8", 29.7 #, L80, Hyd 523 liner
from 252'-3253' MD. Connections made
up with BOL 2000 AG & torque to 12K.
Joints 7-18 were 39 #, P-110, Hyd 523
liner, including 2 XO joints. They were
torque to 17K with BOL 2000 AG. PUW
183K, SOW 75-80K.
252.0 3,253.0
10/28/2023
18:00
10/29/2023
00:00
6.00 INTRM2, CASING PUTB P Run 7-5/8", 29.7 #, L80, Hyd 523 liner
from 3253'-4403' MD. Connections
made up with BOL 2000 AG & torque to
12K. Ran a total of 74 Vulcan Phazer
Flex centralizers & 148 stop collars.
SOW70-80K
3,253.0 4,403.0
10/29/2023
00:00
10/29/2023
01:00
1.00 INTRM2, CASING PUTB P Ran 7-5/8", 29.7 #, L80, Hyd 523 liner
from 4403'-4530' MD. Connections
made up with BOL 2000 AG & torque to
12K. SOW78K.
4,403.0 4,530.0
10/29/2023
01:00
10/29/2023
02:30
1.50 INTRM2, CASING CIRC P Circulated bottoms up. Made up
crossover & FOSV. Screwed in top drive
and circulated. Staged up flow rate .5-3
bpm; FCP 417 psi.
4,530.0 4,530.0
10/29/2023
02:30
10/29/2023
03:00
0.50 INTRM2, CASING PUTB P Ran 7-5/8", 29.7 #, L80, Hyd 523 liner
from 4530'-4662' MD. Connections
made up with BOL 2000 AG & torque to
12K. SOW78K.
4,530.0 4,662.0
10/29/2023
03:00
10/29/2023
03:15
0.25 INTRM2, CASING RURD P Rigged down power tongs & cleared
floor.
4,662.0 4,662.0
10/29/2023
03:15
10/29/2023
04:30
1.25 INTRM2, CASING OTHR P Made up Dril-Quip 7-5/8" X 9-5/8" XPak
liner hanger as per TIW Rep from 4662'-
4715' MD. Installed liner wiper plugs.
SOW 75K.
4,662.0 4,715.0
10/29/2023
04:30
10/29/2023
06:30
2.00 INTRM2, CASING CIRC P Circulated a liner volume from 4715'-
4809' MD. Staged up flow rate .5-5 bpm,
FCP 588 psi.
4,715.0 4,809.0
10/29/2023
06:30
10/29/2023
12:00
5.50 INTRM2, CASING RUNL P Ran 7-5/8" liner on 5-7/8" drill pipe from
4809'-6477' MD. Filled pipe every stand.
15 rpm; Tq 8-10K. RSOW 85-90K.
Obtained T&D at 4809' MD.
1 bpm; 300 psi
20 rpm; Tq 3-6K
PUW 184K
SOW N/A
ROT 136K
RSOW 86K
4,809.0 6,477.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 21/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/29/2023
12:00
10/29/2023
18:00
6.00 INTRM2, CASING RUNL P Ran 7-5/8" liner on 5-7/8" drill pipe from
6477'-8058' MD. Filled pipe every stand.
15 rpm; Tq 10-12K. RSOW 85-90K.
Obtained T&D at 7721' MD.
1 bpm; 520 psi
20 rpm; Tq 6-7K; PUT 8-10K; SOT 12K
PUW 190K
SOW N/A
ROT 142K
RSOW 84K
6,477.0 8,058.0
10/29/2023
18:00
10/30/2023
00:00
6.00 INTRM2, CASING RUNL P Ran 7-5/8" liner on 5-7/8" drill pipe from
8058'-10,376' MD. Topped off pipe every
5 standed.
15 rpm; Tq 10-12K.
RSOW 115-120K.
8,058.0 10,376.0
10/30/2023
00:00
10/30/2023
02:45
2.75 INTRM2, CASING RUNL P Ran 7-5/8" liner on 5-7/8" drill pipe &
HWDP from 10,376'-11,763' MD.
Stopped rotating stands down at 11,209'
MD. Drifted each stand to 2.75". Topped
off pipe every 5 stands. Broke
circulation every 10 stands.
1 bpm; 600 psi
15 rpm; Tq 9-10K.
SOW 112K
RSOW 124K
ROT 140K
10,376.0 11,763.0
10/30/2023
02:45
10/30/2023
04:45
2.00 INTRM2, CASING RUNL P Ran 7-5/8" liner on 5-7/8" HWDP from
11,763'-12,285' MD. Picked up singles
from the pipe shed. Drifted each joint to
2.75". Filled the pipe on the fly. Obtained
torque & drag at 12,254' MD.
PUW 218K
SOW 136K
ROT 169K
20 rpm; Tq 12K
11,763.0 12,285.0
10/30/2023
04:45
10/30/2023
05:45
1.00 INTRM2, CASING WASH P Washed down from 12,285'-12,390' MD
to tag TD with 5K.
.5 bpm; 600 psi
SO 130K
12,285.0 12,390.0
10/30/2023
05:45
10/30/2023
08:30
2.75 INTRM2, CEMENT CIRC P Circulated & conditioned mud for
cementing. Staged up pump rate &
rotated.
.5 - 6 bpm; 600 - 778 psi
20 rpm; Tq 12K
12,390.0 12,376.0
10/30/2023
08:30
10/30/2023
09:15
0.75 INTRM2, CEMENT PULD P Laid down 5-7/8" drill pipe single. Blew
down the top drive.
12,376.0 12,345.0
10/30/2023
09:15
10/30/2023
10:15
1.00 INTRM2, CEMENT RURD P Made up Citadel cement head, XO, 5'
pup to the string. Hooked up cement
hoses.
12,345.0 12,380.0
10/30/2023
10:15
10/30/2023
11:15
1.00 INTRM2, CEMENT CIRC P Staged up pump rate & obtained
parameters.
1-6 bph; 400-780 psi
20 rpm; Tq 11-13 K
12,380.0 12,380.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 22/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/30/2023
11:15
10/30/2023
13:30
2.25 INTRM2, CEMENT CMNT P Lined up to cementers & flooded lines
with 5 bbls of water. Pressure tested
lines to 6500 psi. Batched & pumped 40
bbls of 12.0 ppg MudPush II at 3.8 bpm,
550-420 psi. Dropped bottom dart.
Batched & pumped 145 bbls of 15.8 ppg
class G cement at 5-6 bpm, 455-253
psi. Dropped top dart. Pumped 20 bbls
of water at 5 bpm, 75 psi. Swapped to
rig pump and displaced cement with 9.5
ppg mud at 4.75-6 bpm, 243-1056 psi.
Dropped BOZO plug with 160.2 bbls of
mud pumped. Did not see any pressure
for lower wiper plug latch up. Observed
top wiper plug latch up with 1737 psi.
Bumped the plug with 364.3 bbls
pumped, at 680 psi. Pressured up to
1100 psi & held for 5 minutes. Bled off
pressure and checked floats, good. CIP
13:22 hrs.
12,380.0 12,380.0
10/30/2023
13:30
10/30/2023
14:00
0.50 INTRM2, CEMENT PACK P Pressured up to 5000 psi & held for 10
minutes to set the liner hanger. Bled
pressure to 500 psi. Picked up to 300K
& held for 1 minute. Slacked off to 80K.
12,380.0 12,380.0
10/30/2023
14:00
10/30/2023
15:30
1.50 INTRM2, CEMENT RURD P Rigged down cement line & cement
head. Picked up working single of 5-7/8"
drill pipe.
12,380.0 12,380.0
10/30/2023
15:30
10/30/2023
16:15
0.75 INTRM2, CEMENT PRTS P Set hook load to 110K. Closed annular
& lined up to test liner hanger / packer
top. Pressured up with 4.2 bbls to 2000
psi. Held pressure for 10 minutes, good.
Bled off pressure & opened annular.
12,380.0 7,705.0
10/30/2023
16:15
10/30/2023
18:00
1.75 INTRM2, CEMENT CIRC P Pulled running tool out of liner hanger
from 7705'-7645' MD. Circulated 2
bottoms up. Dropped a foam wiper ball
for each bottoms up. Clear floor & blew
down top drive.
600 gpm; 1200 psi
10 rpm; Tq 3K
7,705.0 7,645.0
10/30/2023
18:00
10/30/2023
18:30
0.50 INTRM2, CEMENT OWFF P Monitored well 30 minutes, static. 7,645.0 7,645.0
10/30/2023
18:30
10/30/2023
19:00
0.50 INTRM2, CEMENT PULD P Laid down working single to pipe shed.
Made up stand in the mouse hole &
racked back stand #75 7645'-7614' MD.
7,645.0 7,614.0
10/30/2023
19:00
10/30/2023
20:00
1.00 INTRM2, CEMENT PULD P Pulled out of the hole laying down
HWDP from 7614'-6911' MD. PUW
160K
7,614.0 6,911.0
10/30/2023
20:00
10/30/2023
23:45
3.75 INTRM2, CEMENT TRIP P Tripped out of the hole racking back 5-
7/8" drill pipe from 6911'-50' MD.
6,911.0 50.0
10/30/2023
23:45
10/31/2023
00:00
0.25 INTRM2, CEMENT TRIP P Tripped out of the hole & inspected liner
hanger running tool to surface.
50.0 0.0
10/31/2023
00:00
10/31/2023
00:45
0.75 INTRM2, CEMENT PULD P Cleaned & prepped liner hanger running
tool for shipping. Laid down to pipe
shed.
0.0 0.0
10/31/2023
00:45
10/31/2023
01:45
1.00 INTRM2, WHDBOP WWWH P Made up stack washing tool to a stand
of 5-7/8" drill pipe. Washed stack &
wellhead with 3 passes at 650 gpm, 20
psi. Laid down tool & racked back stand.
Blew down top drive.
0.0 0.0
10/31/2023
01:45
10/31/2023
04:15
2.50 INTRM2, WHDBOP RURD P Closed blind rams & de-energized
accumulator system. Removed upper 7-
5/8" solid body rams. Installed 3-1/2" X
6-5/8" VBRs. SIMOPS performed
accumulator monthly PM; cut & slipped
75' of drill line; performed brake
inspection; calibrated blocks.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 23/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/31/2023
04:15
10/31/2023
05:00
0.75 INTRM2, WHDBOP RURD P Made up test joint & pups. Made up 5-
7/8" & 4-1/2" floor valves with test
fittings. Energized accumulator system
& opened blind rams.
0.0 0.0
10/31/2023
05:00
10/31/2023
05:45
0.75 INTRM2, WHDBOP RURD P Made up wear ring retrieval tool to the
test joint. Pulled the wear ring, per FMC.
Blew down choke/kill lines. Set test plug
per FMC Rep.
0.0 0.0
10/31/2023
05:45
10/31/2023
07:00
1.25 INTRM2, WHDBOP RURD P Filled BOP stack & choke manifold with
water. Rigged up test fitting to the top
drive. Purged lines of air.
0.0 0.0
10/31/2023
07:00
10/31/2023
14:00
7.00 INTRM2, WHDBOP BOPE P Tested BOPE with 4-1/2" & 5-7/8" test
joints. All equipment tested to 250/3850
psi for 5 minutes each, charted. Annular
tested to 250/2500 psi. Witness waived
by AOGCC Brian Bixby 10-28-23.
#1 Annular with 4-1/2" test joint.
#2 Upper 3-1/2" x 6-5/8" VBRs, CMV
#1,14, 15, 16, Kill line valve #3, & upper
IBOP.
#3 CMV #10, 13, needle valve above
CMV #1, HCR Kill, & lower IBOP.
#4 CMV #4, 9, 12, Manual Kill, & 4-1/2"
FOSV.
#5 CMV #6, 8, 11, & 4-1/2" Dart valve.
#6 CMV #5, 7, & 5-7/8" Dart valve.
#7 CMV #2 & 5-7/8" FOSV.
#8 HCR Choke.
#9 Manual Choke.
#10 Lower 3-1/2" x 6-5/8" VBRs with 4-
1/2" test joint.
#11 Blind Shears, CMV #3, 4, & 6.
#12 Manual choke to 1500 psi.
#13 Electric choke to 1500 psi.
Accumulator drawdown test. System
pressure 3025 psi, Manifold 1500 psi,
after closure1650 psi. Attained 200 psi
in 11 seconds. Full pressure attained in
89 seconds. Control system response
times: annular 17 seconds; upper VBRs
14 seconds; blind/shear 14 seconds;
lower VBRs 15 seconds; HCR Choke 1
second; HCR Kill 1 second. 10 nitrogen
bottles averaged 3850 psi. Gas alarms
tested.
0.0 0.0
10/31/2023
14:00
10/31/2023
18:00
4.00 INTRM2, WHDBOP BOPE T Attempted to change out to 5-7/8" test
joint. While screwing test joint into test
plug, unsure if connection was made up
completely. Picked up a stand of 4-1/2:"
drill pipe. Washed over the connection
of the test plug to ensure no debris in it.
Racked back stand. Drained the stack.
Ran in with test joint & pulled the test
plug to the rig floor. Inspected test plug
connection, good. Ran test plug in on 5-
7/8" test joint and set per FMC. Filled
stack with water & rigged up test
equipment to test joint.
0.0 0.0
10/31/2023
18:00
10/31/2023
18:45
0.75 INTRM2, WHDBOP BOPE P Tested with 5-7/8" test joint to 250/3850
psi, for 5 minutes each test, charted.
#14 Upper 3-1/2" x 6-5/8" VBRs.
#15 Lower 3-1/2" x 6-5/8" VBRs.
0.0 0.0
10/31/2023
18:45
10/31/2023
19:15
0.50 INTRM2, WHDBOP RURD P Pulled test plug. Drained stack. Set
wear ring per FMC Rep.
Wear ring OD 13.42"; ID 8.66"; L 12.5"
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 24/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/31/2023
19:15
10/31/2023
19:45
0.50 INTRM2, WHDBOP RURD P Rigged down test equipment. Blew
down choke & kill lines. Cleaned &
cleared rig floor.
0.0 0.0
10/31/2023
19:45
10/31/2023
20:00
0.25 INTRM2, WHDBOP RURD P Filled stack with 9.5 ppg mud with kill
line. Closed blind / shear rams. Purged
lines.
0.0 0.0
10/31/2023
20:00
10/31/2023
20:45
0.75 INTRM2, WHDBOP PRTS P Tested 9-5/8" X 7-5/8" casing to 4000
psi with 9.5 ppg FWP mud. Pressured
up to 4040 psi with 11.0 bbls. Shut in
and monitored for 30 minutes. Final
pressure 4022 psi. Bled back 11.0 bbls.
0.0 0.0
10/31/2023
20:45
10/31/2023
22:30
1.75 INTRM2, DRILLOUT RURD P Changed out top drive saver sub to 4-
1/2" D425, grabber blocks, & 4-1/2" bell
guide. Serviced top drive. SIMOPS
performed derrick inspection; mobilize
BHA components to the rig floor.
0.0 0.0
10/31/2023
22:30
10/31/2023
23:15
0.75 INTRM2, DRILLOUT BHAH P Mobilize remaining BHA components to
the rig floor.
0.0 0.0
10/31/2023
23:15
11/1/2023
00:00
0.75 INTRM2, DRILLOUT BHAH P Made 36' MD of BHA & staged back in
the pipe shed.
0.0 0.0
11/1/2023
00:00
11/1/2023
02:15
2.25 INTRM2, DRILLOUT BHAH P Made up 6-1/2" production BHA as per
SLB & HES to 255' MD.
0.0 255.0
11/1/2023
02:15
11/1/2023
03:30
1.25 INTRM2, DRILLOUT TRIP P Tripped in the hole on 4-1/2" drill pipe in
the derrick from 255'-2135' MD. SOW
106K
255.0 2,135.0
11/1/2023
03:30
11/1/2023
04:00
0.50 INTRM2, DRILLOUT DHEQ P Shallow hole tested MWD tools, good.
Blew down top drive.
240 gpm; 1280 psi
40 rpm; Tq 2K
RTW 108K
2,135.0 2,135.0
11/1/2023
04:00
11/1/2023
08:45
4.75 INTRM2, DRILLOUT TRIP P Tripped in the hole on 4-1/2" drill pipe in
the derrick from 2135'-7705' MD. SOW
120K
2,135.0 7,705.0
11/1/2023
08:45
11/1/2023
10:00
1.25 INTRM2, DRILLOUT DRLG P Reamed down from 7705'-7715' tagging
drillable pack off bushing. Drill out
DPOB from 7715'-7720' MD. Reamed 2
times. Blew down top drive.
240 gpm; 1470 psi
40 rpm; Tq 4-8K
WOB 3-8K
RTW 135K
7,705.0 7,720.0
11/1/2023
10:00
11/1/2023
11:30
1.50 INTRM2, DRILLOUT TRIP P Tripped in the hole on 4-1/2" drill pipe in
the derrick from 7720'-8927' MD. SOW
107K. Logged free ring pipe at 1800 fph
from 7839'-8927' MD.
7,720.0 8,927.0
11/1/2023
11:30
11/1/2023
12:30
1.00 INTRM2, DRILLOUT PULD P Tripped in the hole picking up 4-1/2" drill
pipe from 8927'-9212' MD. Sonic logged
cement.
SOW 106K
1800 fph
8,927.0 9,212.0
11/1/2023
12:30
11/1/2023
13:00
0.50 INTRM2, DRILLOUT OTHR P Filled pipe and tested Amphion torque
release for NOV. Blew down top drive.
9,212.0 9,212.0
11/1/2023
13:00
11/1/2023
17:45
4.75 INTRM2, DRILLOUT PULD P Tripped in the hole picking up 4-1/2" drill
pipe from 9212'-11,634' MD. Sonic
logged cement. Filled pipe every 20
stands. Set down weight at 11,634' MD
with 20K.
PUW 167K
SOW 96K
1800 fph
9,212.0 11,634.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 25/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/1/2023
17:45
11/1/2023
19:30
1.75 INTRM2, DRILLOUT REAM P Attempted to ream through tight
clearance and tag up at 11,632' MD,
with weight & torque stalled out.
Released torque and picked up to 232K
to break over. Established pump and
rotation, reaming through top of 7-5/8"
39# liner to 11,665' MD.
200 gpm; 1325 psi
40 rpm; Tq 7-10K
PUW 169K
SOW 100K
RTW 134K
11,634.0 11,665.0
11/1/2023
19:30
11/1/2023
20:45
1.25 INTRM2, DRILLOUT PULD P Tripped in the hole picking up 4-1/2" drill
pipe from 11665'-12,009' MD. Sonic
logged cement. Observed cement
stringers at 12,009' MD.
SOW 99-84K
1800 fph
11,665.0 12,009.0
11/1/2023
20:45
11/1/2023
22:30
1.75 INTRM2, DRILLOUT REAM P Reamed from 12,009'-12,126' MD.
Tagged plugs with 7K WOB.
200 gpm; 1300 psi
40 rpm; Tq 8-10K
RSOW 129K
12,009.0 12,126.0
11/1/2023
22:30
11/1/2023
23:15
0.75 INTRM2, DRILLOUT MPDA P Installed 4-1/2" MPD bearing as per
Advisor. Circulated through system to
verify choke functions.
12,126.0 12,125.0
11/1/2023
23:15
11/2/2023
00:00
0.75 INTRM2, DRILLOUT DISP P Started displacement from 9.5 ppg FWP
to 8.2 ppg Versaclean OBM. Pumped
100 bbls of Deepclean spacer. Chased
with 45 bbls of 8.2 ppg Versaclean OBM
at 24:00hrs.
250 gpm; 2051 psi
40 rpm; Tq 8-11K
PUW 130K
SOW 124K
RTW 129K
12,125.0 12,125.0
11/2/2023
00:00
11/2/2023
02:00
2.00 INTRM2, DRILLOUT DISP P Finished displacement from 9.5 ppg
FWP to 8.2 ppg Versaclean OBM.
Pumped 840 bbls total to see good
OBM at surface, including 100 bbls of
spacer train & 28 bbls of interface.
250 gpm; 2068 psi
60 rpm; Tq 7K
PUW 139K
SOW 125K
RTW 134K
12,125.0 12,125.0
11/2/2023
02:00
11/2/2023
03:00
1.00 INTRM2, DRILLOUT OWFF P Performed negative pressure test.
Trapped 300 psi with MPD. Stepped
down pressure incrementally to full open
choke to the pits. No flow observed at
the pits. Monitored no flow for 30
minutes in the BOP deck, from 2" line,
directly off the RCD.
12,125.0 12,125.0
11/2/2023
03:00
11/2/2023
03:30
0.50 INTRM2, DRILLOUT CIRC P Set seats in #3 mud pump. Established
circulation with back pressure pump.
Obtained SCRs with MP #1 & 2.
12,125.0 12,125.0
11/2/2023
03:30
11/2/2023
06:00
2.50 INTRM2, DRILLOUT DRLG P Drilled out plugs & landing collar from
12,125'-12,131' MD. Maintained 9.1
EMW with MPD.
200-220 gpm; 1360-1700 psi
60 rpm; Tq 8-10K
WOB 5-12K
ECD 9.1
12,125.0 12,131.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 26/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/2/2023
06:00
11/2/2023
11:45
5.75 INTRM2, DRILLOUT DRLG P Drilled out shoe track from 12,131'-
12,136' MD. Maintained 9.6 EMW with
MPD.
100-200 gpm; 700-1600 psi
20-100 rpm; Tq 4-12K
WOB 5-35K
12,131.0 12,136.0
11/2/2023
11:45
11/2/2023
21:00
9.25 INTRM2, DRILLOUT DRLG P Drilled out shoe track from 12,136'-
12,161' MD. Used varied parameters.
Picked up several times to ensure no
debris in the bit or around the BHA.
Pumped 20 bbls of 15 ppb NMP pill @
12,152' MD. No changes noted.
Maintained 9.6 EMW with MPD.
42-240 gpm; 440-1900 psi
5-121 rpm; Tq 3-18K
WOB 5-35K
12,136.0 12,161.0
11/2/2023
21:00
11/3/2023
00:00
3.00 INTRM2, DRILLOUT DRLG P Drilled out shoe track from 12,161'-
12,171' MD. Used varied parameters.
Picked up several times to ensure no
debris in the bit or around the BHA.
Maintained 9.6 EMW with MPD.
250 gpm; 2060 psi
40-120 rpm; Tq 7-12K
WOB 10-25K
12,161.0 12,171.0
11/3/2023
00:00
11/3/2023
06:00
6.00 INTRM2, DRILLOUT DRLG P Drilled out shoe track from 12,171'-
12,222' MD. Picked up several times to
ensure no debris in the bit or around the
BHA. Maintained 9.6 EMW with MPD.
250 gpm; 2035 psi
140 rpm; Tq 8-10K
WOB 16-25K
12,171.0 12,222.0
11/3/2023
06:00
11/3/2023
12:00
6.00 INTRM2, DRILLOUT DRLG P Drilled out shoe track from 12,222'-
12,282' MD. Used varied parameters.
Picked up several times to ensure no
debris in the bit or around the BHA.
Float collar drilled at 12,254' MD.
Maintained 9.6 EMW with MPD.
100-250 gpm; 720-2035 psi
80-140 rpm; Tq 8-15K
WOB 10-34K
12,222.0 12,282.0
11/3/2023
12:00
11/3/2023
14:00
2.00 INTRM2, DRILLOUT DRLG P Drilled out shoe track from 12,282'-
12,378' MD. Maintained 9.6 EMW with
MPD.
225 gpm; 1777 psi
140 rpm; Tq 9K
WOB 8-12K
12,282.0 12,378.0
11/3/2023
14:00
11/3/2023
17:15
3.25 INTRM2, DRILLOUT DRLG P Drilled out float shoe & rat hole from
12,378'-12,390' MD. Maintained 9.6
EMW with MPD.
225 gpm; 1744 psi
100 rpm; Tq 10K
WOB 20-28K
12,378.0 12,390.0
11/3/2023
17:15
11/3/2023
17:30
0.25 INTRM2, DRILLOUT DDRL P Drilled 6-1/2" production section from
12,390'-12,410' MD, 4071' TVD.
Maintained 9.6 EMW with MPD.
225 gpm; 1745 psi
100 rpm; Tq on 10K, off
WOB 20-28K
ECD 9.6
PUW 175K
SOW 98K
RTW 141K
Total Gas 5
ADT .17; Bit hrs .17
12,390.0 12,410.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 27/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/3/2023
17:30
11/3/2023
19:45
2.25 INTRM2, DRILLOUT CIRC P Circulated bottoms up & conditioned
mud for FIT. Pumped 570 bbls.
260 gpm; 2168 psi
90 rpm; Tq 9K
ECD 9.62
12,410.0 12,324.0
11/3/2023
19:45
11/3/2023
21:00
1.25 INTRM2, DRILLOUT FIT P Lined up / isolated MPD & trapped 305
psi on well bore. Pumped 8.2 ppg OBM,
pressuring up from 305-1017 psi with 2
bbls pumped. Shut in and monitored
pressure for 10 minutes. Final pressure
recorded 969 psi. Lined up MPD. Bled
back 1.8 bbls to 300 psi. Aligned valves
for drilling. FIT at the intermediate 2
shoe, 4070' TVD, 13.0 ppg EMW.
12,324.0 12,324.0
11/3/2023
21:00
11/3/2023
21:45
0.75 PROD1, DRILL SVRG P Broke off stand 129 and staged in the
mouse hole. Changed out grabber dies
on the top drive. Made up stand 129 &
washed down to 12,410' MD.
12,324.0 12,410.0
11/3/2023
21:45
11/4/2023
00:00
2.25 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
12,410'-12,512' MD, 4080' TVD.
Maintained 9.6 EMW with MPD.
260 gpm; 2208 psi
120 rpm; Tq on 10K, off 5K
WOB 7K
ECD 9.74
PUW 175K
SOW 98K
RTW 141K
Total Gas 11
ADT 1.36; Bit hrs 1.53
12,410.0 12,512.0
11/4/2023
00:00
11/4/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
12,512'-12,934' MD, 4105' TVD.
Maintained 9.6 EMW with MPD.
260 gpm; 2216 psi
120 rpm; Tq on 11K, off 5K
WOB 14K
ECD 9.75
PUW 175K
SOW 98K
RTW 141K
Total Gas 280
ADT 4.81; Bit hrs 6.34
12,512.0 12,934.0
11/4/2023
06:00
11/4/2023
11:30
5.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
12,934'-13,361' MD, 4132' TVD.
Maintained 9.6 EMW with MPD.
270 gpm; 2400 psi
120 rpm; Tq on 9K, off 5K
WOB 10K
ECD 9.86
PUW 178K
SOW 96K
RTW 143K
Total Gas 355
ADT 4.28; Bit hrs 10.62
12,934.0 13,361.0
11/4/2023
11:30
11/4/2023
12:00
0.50 PROD1, DRILL SVRG P Serviced and inspected top drive. 13,361.0 13,361.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 28/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/4/2023
12:00
11/4/2023
17:30
5.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
13,361'-13,834' MD, 4135' TVD.
Maintained 9.6 EMW with MPD.
270 gpm; 2538 psi
120 rpm; Tq on 12K, off 7K
WOB 9K
ECD 9.75
PUW 183K
SOW N/A
RTW 140K
Total Gas 203
ADT 3.78; Bit hrs 14.40
13,361.0 13,834.0
11/4/2023
17:30
11/4/2023
19:15
1.75 PROD1, DRILL CIRC P Circulated bottoms up reciprocating.
270 gpm; 2475 psi
90 rpm; Tq 9K
ECD 10.07
RPUW 137K
RSOW 127K
13,834.0 13,834.0
11/4/2023
19:15
11/4/2023
22:15
3.00 PROD1, DRILL OWFF P Shut in with MPD at 305 psi. Observed
pressure dropping. Checked surface
equipment and determined pressure
loss was down hole. Began draw down
at 115 psi with 10 psi increments. Final
draw down was done 2 times;
monitoring from 46 psi, building up to 57
psi. Pore pressure calculated at 8.7 ppg
EMW with 8.4 ppg mud in the hole at
4070' TVD.
13,834.0 13,834.0
11/4/2023
22:15
11/4/2023
22:45
0.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
13,834'-13,889' MD, 4133' TVD.
Maintained 9.6 EMW with MPD.
270 gpm; 2557 psi
120 rpm; Tq on 12K, off 7K
WOB 10K
ECD 10.4
PUW 183K
SOW N/A
RTW 140K
Total Gas 116
ADT .46; Bit hrs 14.86
13,834.0 13,889.0
11/4/2023
22:45
11/5/2023
00:00
1.25 PROD1, DRILL CIRC T Observed flow restriction with pressure
& ECD increases. Picked up off bottom
and adjusted flow rates to clear flow
restriction.
220-270 psi; 1821-2977 psi
120 rpm; Tq 8K
ECD 10.16-11.4
13,889.0 13,889.0
11/5/2023
00:00
11/5/2023
00:30
0.50 PROD1, DRILL CIRC T Continued to clear flow restriction.
270 psi; 2489 psi
120 rpm; Tq 8K
ECD 10.17
13,889.0 13,889.0
11/5/2023
00:30
11/5/2023
06:00
5.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
13,889'-14,452' MD, 4134' TVD.
Maintained 9.6 EMW with MPD.
270 gpm; 2550 psi
120 rpm; Tq on 13K, off 6K
WOB 13K
ECD 10.15
PUW 186K
SOW N/A
RTW 135K
Total Gas 309
ADT 4.15; Bit hrs 19.01
Day light savings at 2 am rolled clocks
back 1 hour.
13,889.0 14,452.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 29/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/5/2023
06:00
11/5/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
14,452'-14,908' MD, 4141' TVD.
Maintained 9.6 EMW with MPD.
270 gpm; 2602 psi
120 rpm; Tq on 14K, off 7K
WOB 4-8K
ECD 10.26
PUW 187K
SOW N/A
RTW 136K
Total Gas 309
ADT 4.89; Bit hrs 23.90
14,452.0 14,908.0
11/5/2023
12:00
11/5/2023
18:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
14,908'-15,417' MD, 4156' TVD.
Maintained 9.6 EMW with MPD.
270 gpm; 2707 psi
120 rpm; Tq on 13K, off 12K
WOB 12K
ECD 10.44
PUW 193K
SOW N/A
RTW 135K
Total Gas 214
ADT 4.35; Bit hrs 28.25
14,908.0 15,417.0
11/5/2023
18:00
11/6/2023
00:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
15,417'-15,814' MD, 4167' TVD.
Maintained 9.6 EMW with MPD.
290 gpm; 3070 psi
110 rpm; Tq on 13K, off 7K
WOB 4K
ECD 10.68
PUW 194K
SOW N/A
RTW 135K
Total Gas 200
ADT 4.40; Bit hrs 32.65
15,417.0 15,814.0
11/6/2023
00:00
11/6/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
15,814'-16,069' MD, 4163' TVD.
Maintained 9.6 EMW with MPD.
Obtained SCRs.
290 gpm; 2958 psi
110 rpm; Tq on 14K, off 7K
WOB 4-6K
ECD 10.44
PUW 194K
SOW N/A
RTW 135K
Total Gas 230
ADT 5.01; Bit hrs 37.66
15,814.0 16,069.0
11/6/2023
06:00
11/6/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
16,069'-16,481' MD, 4176' TVD.
Maintained 9.6 EMW with MPD.
290 gpm; 3032 psi
110 rpm; Tq on 13K, off 12K
WOB 10K
ECD 10.63
PUW 195K
SOW N/A
RTW 134K
Total Gas 230
ADT 4.96; Bit hrs 42.62
16,069.0 16,481.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 30/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/6/2023
12:00
11/6/2023
18:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
16,481'-16,879' MD, 4169' TVD.
Maintained 9.6 EMW with MPD.
Obtained SCRs.
290 gpm; 3060 psi
110 rpm; Tq on 13K, off 13K
WOB 6-10K
ECD 10.68
PUW 201K
SOW N/A
RTW 136K
Total Gas 274
ADT 4.83; Bit hrs 47.45
16,481.0 16,879.0
11/6/2023
18:00
11/7/2023
00:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
16,879'-17,216' MD, 4173' TVD.
Maintained 9.6 EMW with MPD.
290 gpm; 3115 psi
110 rpm; Tq on 14K, off 12K
WOB 7K
ECD 10.76
PUW 193K
SOW N/A
RTW 135K
Total Gas 274
ADT 5.15; Bit hrs 52.60
16,879.0 17,216.0
11/7/2023
00:00
11/7/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
17,216'-17,513' MD, 4185' TVD.
Maintained 9.6 EMW with MPD.
Obtained SCRs.
290 gpm; 3150 psi
110 rpm; Tq on 14K, off 11K
WOB 12K
ECD 10.67
PUW 194K
SOW N/A
RTW 125K
Total Gas 203
ADT 4.82; Bit hrs 57.42
17,216.0 17,513.0
11/7/2023
06:00
11/7/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
17,513'-17,798' MD, 4192' TVD.
Maintained 9.6 EMW with MPD.
290 gpm; 3140 psi
110 rpm; Tq on 14K, off 11K
WOB 12K
ECD 10.83
PUW 202K
SOW N/A
RTW 137K
Total Gas 203
ADT 4.94; Bit hrs 62.36
17,513.0 17,798.0
11/7/2023
12:00
11/7/2023
16:00
4.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
17,798'-18,079' MD, 4187' TVD.
Maintained 9.6 EMW with MPD.
290 gpm; 3162 psi
110 rpm; Tq on 15K, off 12K
WOB 12K
ECD 11.03
PUW 204K
SOW N/A
RTW 138K
Total Gas 185
ADT 3.16; Bit hrs 65.52
17,798.0 18,079.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 31/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/7/2023
16:00
11/7/2023
20:00
4.00 PROD1, DRILL RGRP T Replaced dies on the top drive grabber.
Attempted to break out of stand #189
with top drive, had to use rig tongs to
break connection. Racked back stand #
189. Inspected top box end of stand
#188 & noted damage from over torque.
Laid down top joint of #188. Blew down
top drive. Made up head pin and
circulated at 63 gpm; 700 psi. Changed
out top drive grabber dies. Changed out
saver sub.
18,079.0 17,923.0
11/7/2023
20:00
11/7/2023
22:00
2.00 PROD1, DRILL REAM T Staged up circulation and rotation to 290
gpm; 3276 psi; 110 rpm; Tq 13K. Picked
up single to replace the top joint of stand
#188. Adjusted tally to remove over
torque stand. Washed and reamed from
17,923'-18,079' MD.
17,923.0 18,079.0
11/7/2023
22:00
11/8/2023
00:00
2.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
18,079'-18,250' MD, 4187' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
290 gpm; 3242 psi
110 rpm; Tq on 15K, off 8K
WOB 12K
ECD 11.09
PUW 205K
SOW N/A
RTW 136K
Total Gas 202
ADT 1.48; Bit hrs 67.0
18,079.0 18,250.0
11/8/2023
00:00
11/8/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
18,250'-18,691' MD, 4185' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
290 gpm; 3276 psi
110 rpm; Tq on 14K, off 9K
WOB 8K
ECD 11.25
PUW 209K
SOW N/A
RTW 135K
Total Gas 254
ADT 4.29; Bit hrs 71.29
18,250.0 18,691.0
11/8/2023
06:00
11/8/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
18,691'-19.029' MD, 4194' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
270 gpm; 2928 psi
110 rpm; Tq on 13K, off 12K
WOB 8K
ECD 11.00
PUW 211K
SOW N/A
RTW 136K
Total Gas 154
ADT 4.85; Bit hrs 76.14
18,691.0 19,029.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 32/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/8/2023
12:00
11/8/2023
13:15
1.25 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19029'-19.116' MD, 4197' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
270 gpm; 2920 psi
110 rpm; Tq on 13K, off 9K
WOB 8K
ECD 11.08
PUW 205K
SOW N/A
RTW 136K
Total Gas 93
ADT 1.19; Bit hrs 77.33
19,029.0 19,116.0
11/8/2023
13:15
11/8/2023
15:45
2.50 PROD1, DRILL SFTY P Safety stand down with all personnel on
rig, Joint call in Via Teams with CPAI
town and DDI office and rig personnel.
Circulate while reciprocate and rotate at
270 GPM, 70 RPM
19,116.0 19,116.0
11/8/2023
15:45
11/8/2023
18:00
2.25 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19116'-19.210' MD, 4198' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
270 gpm; 2941 psi
110 rpm; Tq on 13K, off 9K
WOB 4K
ECD 11.08
PUW 205K
SOW N/A
RTW 136K
Total Gas 128
ADT 1.53; Bit hrs 78.86
19,116.0 19,210.0
11/8/2023
18:00
11/9/2023
00:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19210'-19.500' MD, 4200' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
270 gpm; 2977 psi
110 rpm; Tq on 14K, off 9K
WOB 4K
ECD 11.07
PUW 205K
SOW N/A
RTW 136K
Total Gas 120
ADT 4.94; Bit hrs 83.80
19,210.0 19,500.0
11/9/2023
00:00
11/9/2023
03:30
3.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19500'-19.778' MD, 4195' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
270 gpm; 3023 psi
110 rpm; Tq on 15K, off 13K
WOB 16K
ECD 11.16
PUW 222K
SOW N/A
RTW 136K
Total Gas 157
ADT 4.94; Bit hrs 83.80
19,500.0 19,778.0
11/9/2023
03:30
11/9/2023
06:00
2.50 PROD1, DRILL WAIT T Phase 3 conditions, stop drilling.
Circulate and reciprocate until weather
conditions improve.
19,778.0 19,778.0
11/9/2023
06:00
11/9/2023
12:00
6.00 PROD1, DRILL WAIT T Phase 3 conditions. Circulate and
reciprocate until weather conditions
improve.
19,778.0 19,778.0
11/9/2023
12:00
11/9/2023
18:00
6.00 PROD1, DRILL WAIT T Phase 3 conditions. Circulate and
reciprocate until weather conditions
improve.
19,778.0 19,778.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 33/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/9/2023
18:00
11/10/2023
00:00
6.00 PROD1, DRILL WAIT T Phase 3 conditions. Circulate and
reciprocate until weather conditions
improve.
19,778.0 19,778.0
11/10/2023
00:00
11/10/2023
06:00
6.00 PROD1, DRILL WAIT T Phase 3 conditions, stop drilling and
circulate and reciprocate until weather
conditions improve.
19,778.0 19,778.0
11/10/2023
06:00
11/10/2023
12:00
6.00 PROD1, DRILL WAIT T Phase 3 conditions, stop drilling and
circulate and reciprocate until weather
conditions improve.
19,778.0 19,778.0
11/10/2023
12:00
11/10/2023
18:00
6.00 PROD1, DRILL WAIT T Phase 3 conditions, stop drilling and
circulate and reciprocate until weather
conditions improve.
19,778.0 19,778.0
11/10/2023
18:00
11/10/2023
23:00
5.00 PROD1, DRILL WAIT T Phase 3 conditions, stop drilling and
circulate and reciprocate until weather
conditions improve.
09:30 Rack back one stand.
19,778.0 19,778.0
11/10/2023
23:00
11/11/2023
00:00
1.00 PROD1, DRILL CIRC P Phase condition lifted , wash to bottom
and record slow pump rates.
19,778.0 19,778.0
11/11/2023
00:00
11/11/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19778'-20,253' MD, 4198' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
260 gpm; 2948 psi
110 rpm; Tq on 15K, off 13K
WOB 11K
ECD 11.18
PUW 233K
SOW N/A
RTW 137K
Total Gas 141
ADT 4.65; Bit hrs 91.03
19,778.0 20,253.0
11/11/2023
06:00
11/11/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
20253'-20,668' MD, 4202' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
270 gpm; 2959 psi
110 rpm; Tq on 14K, off 9K
WOB 11K
ECD 11.16
PUW 229K
SOW N/A
RTW 133K
Total Gas 264
ADT 4.47; Bit hrs 95.50
20,253.0 20,668.0
11/11/2023
12:00
11/11/2023
16:30
4.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
20668'-20,995' MD, 4208' TVD.
Maintained 9.6 EMW at 7-5/8" shoe,
with MPD.
270 gpm; 3003 psi
110 rpm; Tq on 16K, off 13K
WOB 13K
ECD 11.29
PUW 225K
SOW N/A
RTW 136K
Total Gas 287
ADT 4.47; Bit hrs 95.50
20,668.0 20,995.0
11/11/2023
16:30
11/11/2023
16:45
0.25 PROD1, TRIPCAS CIRC P TD called by town geologist. Obtain final
torque and drag numbers slow pump
rates and down link.
20,995.0 20,995.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 34/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/11/2023
16:45
11/12/2023
00:00
7.25 PROD1, TRIPCAS CIRC P Circulate and reciprocate from 20,995'
to 20,920'
While preparing pits for displacment to
KWM.
GPM = 270
PSI = 2963
RPM = 110
TQ = 13k
ECD = 10.93
20,995.0 20,995.0
11/12/2023
00:00
11/12/2023
01:30
1.50 PROD1, TRIPCAS CIRC P Circulate and reciprocate from 20,995'
to 20,920'
While preparing pits for displacement to
KWM.
GPM = 270
PSI = 2963
RPM = 110
TQ = 13k
ECD = 10.93
Conduct PJSM for displacement
20,995.0 20,995.0
11/12/2023
01:30
11/12/2023
05:30
4.00 PROD1, TRIPCAS DISP P PJSM and Displace 8.2 MDWT to 9.6
KWM while reciprocate from 20,994' to
20,920' as per Beyond rollover
schedule.
GPM = 250
PSI = 2947
RPM = 80
Highest ECD = 11.93
Total strokes pumped = 11,517
Collect slow pump rates and blow down
top drive.
20,995.0 20,995.0
11/12/2023
05:30
11/12/2023
08:00
2.50 PROD1, TRIPCAS OWFF P Perform flow check while preparing rig
for stripping operations.
20,995.0 20,995.0
11/12/2023
08:00
11/12/2023
12:00
4.00 PROD1, TRIPCAS SMPD P Strip out of hole utilizing MPD to offset
swab from 20,995' to 16,958' MD
PUW = 182K
SPB = 290 PSI
Monitor displacment via pit #5
20,995.0 16,958.0
11/12/2023
12:00
11/12/2023
15:30
3.50 PROD1, TRIPCAS SMPD P Strip out of hole utilizing MPD to offset
swab from 16,958' to 12,375' MD
PUW = 165K
SPB = 290 PSI
Monitor displacment via pit #5
16,958.0 12,375.0
11/12/2023
15:30
11/12/2023
16:30
1.00 PROD1, TRIPCAS CIRC P Circulate and cycle pumps attempting to
wake up tools
GPM = 250
PSI = 2280
RPM = 30
TQ = 4K
Simops Prepare ST 120's for head
repair.
12,375.0 12,375.0
11/12/2023
16:30
11/12/2023
17:15
0.75 PROD1, TRIPCAS CIRC P Drop 1.75" steel ball for well
commander as per DD, pump down at
250 GPM, 2301 PSI, drop to 75 GPM at
718 strokes 450 PSI, 949 strokes ball on
seat pressure increase to 2985 to open
well commander. verify open with 250
GPM @ 812 PSI.
12,375.0 12,375.0
11/12/2023
17:15
11/12/2023
19:00
1.75 PROD1, TRIPCAS CIRC P Circulate and reciprocate from 12,375'
to 12,315' from 300 GPM to 500 GPM
until shakers clean up
12,375.0 12,375.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 35/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/12/2023
19:00
11/12/2023
19:45
0.75 PROD1, TRIPCAS CIRC P Drop 1.75" steel ball for well
commander closing as per DD, pump
down at 250 GPM, 752 PSI, drop to 75
GPM at 700 strokes 208 PSI, 906
strokes ball on seat pressure increase to
2782 to close well commander. verify
closed with 250 GPM @ 2308 PSI.
12,375.0 12,375.0
11/12/2023
19:45
11/12/2023
22:00
2.25 PROD1, TRIPCAS OWFF P Perform flow check allow well to breath
back and verify static for 30 minutes.
SIMOPS B/D top drive.
12,375.0 12,375.0
11/12/2023
22:00
11/13/2023
00:00
2.00 PROD1, TRIPCAS SMPD P Strip out of hole utilizing MPD to offset
swab from 12,375' to 11,000' MD
PUW = 151K
SPB = 210 PSI
Monitor displacement via pit #5
12,375.0 11,000.0
11/13/2023
00:00
11/13/2023
06:00
6.00 PROD1, TRIPCAS SMPD P Strip out of hole utilizing MPD to offset
swab from 11,000' to 3,000' MD
PUW = 151K
SPB = 180 PSI
Monitor displacement via pit #5
11,000.0 3,000.0
11/13/2023
06:00
11/13/2023
07:30
1.50 PROD1, TRIPCAS SMPD P Strip out of hole utilizing MPD to offset
swab from 3,000' to 1,000' MD
PUW = 92K
SPB = 180 PSI
Monitor displacement via pit #5
3,000.0 1,000.0
11/13/2023
07:30
11/13/2023
08:00
0.50 PROD1, TRIPCAS OWFF P Perform flow check
SIMOPS: PJSM for RCD bearing
removal and clean and clear rig floor.
1,000.0 1,000.0
11/13/2023
08:00
11/13/2023
08:30
0.50 PROD1, TRIPCAS MPDA P Remove RCD bearing as per SOP. 1,000.0 1,000.0
11/13/2023
08:30
11/13/2023
09:15
0.75 PROD1, TRIPCAS TRIP P Pull out of hole from 1000' to 256'
PUW = 82K
Monitor well Via pit #5
1,000.0 256.0
11/13/2023
09:15
11/13/2023
16:00
6.75 PROD1, TRIPCAS BHAH P PJSM and L/D BHA as per directional
driller.
Clean clear rig floor and inspect BHA.
Replace saver sub to VX-57 for lower
completions run.
256.0 0.0
11/13/2023
16:00
11/13/2023
18:00
2.00 COMPZN, CASING PUTB P M/U shoe track for 4-1/2" HYD 563 liner
and run in hole with completion packers
and frac sleeves as per tally. torque to
5600k with best o life artic grade 2000
pipe dope.
Monitor displacement via trip tank.
From surface to 753' MD
0.0 753.0
11/13/2023
18:00
11/14/2023
00:00
6.00 COMPZN, CASING PUTB P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally. torque to
5600k with best o life artic grade 2000
pipe dope.
Monitor displacement via trip tank.
From 753' MD to 6164' MD
SOW = 90K
753.0 6,164.0
11/14/2023
00:00
11/14/2023
02:45
2.75 COMPZN, CASING PUTB P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally. torque to
5600k with best o life artic grade 2000
pipe dope.
Monitor displacement via trip tank.
From 6164' MD to 8872 ' MD
SOW = 90K
6,164.0 8,872.0
11/14/2023
02:45
11/14/2023
03:45
1.00 COMPZN, CASING THGR P PJSM and P/U and M/U SLZXP 4-1/2"
x 7-5/8" liner hanger as per Baker rep.
8,872.0 8,872.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 36/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/14/2023
03:45
11/14/2023
06:00
2.25 COMPZN, CASING RUNL P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally on 4-1/2"
drillpipe from derrick, fill pipe every 10
stands on top of Arsenal float sub.
Monitor displacement via trip tank.
From 8,872' MD to 11,740 ' MD
PUW = 94
SOW = 90K
8,872.0 11,740.0
11/14/2023
06:00
11/14/2023
12:00
6.00 COMPZN, CASING RUNL P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally on 4-1/2"
drillpipe from derrick, fill pipe every 10
stands on top of Arsenal float sub.
Monitor displacement via trip tank.
From 11,740' MD to 16,125 ' MD
PUW = 127
SOW = 113K
RTW = 120K
11,740.0 16,125.0
11/14/2023
12:00
11/14/2023
15:00
3.00 COMPZN, CASING RUNL P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally on 4-1/2"
drillpipe from derrick, fill pipe every 10
stands on top of Arsenal float sub.
Rotate at 20 RPM as needed.
Monitor displacement via trip tank.
From 16,125' MD to 17,024 ' MD
PUW = 150
SOW = 92K
RTW = 112K
TQ = 5K
16,125.0 17,024.0
11/14/2023
15:00
11/14/2023
15:30
0.50 COMPZN, CASING RURD P Swap drill pipe handling equipment to 5-
7/8" drill pipe.
17,024.0 17,024.0
11/14/2023
15:30
11/14/2023
18:00
2.50 COMPZN, CASING RUNL P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally on 5-7/8"
drillpipe from derrick, fill pipe every 10
stands on top of Arsenal float sub.
Rotate at 20 RPM as needed.
Monitor displacement via trip tank.
From 17,024' MD to 18,046 ' MD
RTW = 122K
TQ = 5K
17,024.0 18,046.0
11/14/2023
18:00
11/15/2023
00:00
6.00 COMPZN, CASING RUNL P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally on 5-7/8"
drillpipe from derrick, fill pipe every 10
stands on top of Arsenal float sub.
Rotate at 20 RPM as needed.
Monitor displacement via trip tank.
From 18,046' MD to 19,990 ' MD
RTW = 145K
TQ = 6-8K
18,046.0 19,990.0
11/15/2023
00:00
11/15/2023
06:00
6.00 COMPZN, CASING RUNL P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally on 5-7/8"
drillpipe from derrick, fill pipe every 10
stands on top of Arsenal float sub.
Rotate at 20 RPM as needed.
Monitor displacement via trip tank.
From 19,990' MD to 20,938' MD
PUW = 200K
SOW = 121
RTW = 157K
TQ = 6-8K
19,990.0 20,938.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 37/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/15/2023
06:00
11/15/2023
07:30
1.50 COMPZN, CASING RUNL P Run lower completions (Float) 4-1/2"
HYD 563 liner with completion packers
and frac sleeves as per tally on 5-7/8"
drillpipe from derrick, fill pipe every 10
stands on top of Arsenal float sub.
Rotate at 20 RPM as needed.
Monitor displacement via trip tank.
From 20,938' MD to 20,958' MD
RTW = 154K
TQ = 9K
20,938.0 20,958.0
11/15/2023
07:30
11/15/2023
08:30
1.00 COMPZN, CASING RURD P Rig up surface equipment to vent and fill
tubing.
20,958.0 20,958.0
11/15/2023
08:30
11/15/2023
09:00
0.50 COMPZN, CASING PACK P Set SLZXP Liner hanger as per
procedure. Pull 190K and pressure up to
3000 psi and hold for 5 minutes. Bleed
down to 500 psi and slack off to 80K,
and bleed off to 0 psi.
20,958.0 20,958.0
11/15/2023
09:00
11/15/2023
09:30
0.50 COMPZN, CASING PRTS T Attempt pressure test hanger packer,
pressure up to 630 psi down annulus
with pipe rams closed and note a 40K
increase in hook load. Consult with
town.
20,958.0 20,958.0
11/15/2023
09:30
11/15/2023
10:30
1.00 COMPZN, CASING PRTS T Bleed off pressure and P/U to 230K
Broke over free travel 190K pressure up
to 1425 psi down backside with upper
VBR's closed , hook load increase to
120K . Consult with town.
20,958.0 20,958.0
11/15/2023
10:30
11/15/2023
12:00
1.50 COMPZN, CASING PRTS P With 120K hook load pressure up
backside with upper VBR's closed to
3850 psi and hold for 10 minutes, 93
total strokes pumped.
20,958.0 20,958.0
11/15/2023
12:00
11/15/2023
12:30
0.50 COMPZN, CASING PACK P Pressure up down drill string to 3600
and hold for 10 minutes, hoist string and
no loss of weight. consult town and
perform mechanical release from liner
hanger as per Baker rep.
20,958.0 12,042.0
11/15/2023
12:30
11/15/2023
13:30
1.00 COMPZN, CASING THGR P PU to expose dogs, rotate and perform
mechanical weight set procedure. 20
RPM, applied 35K wt. Pump down string
to burst arsenal floatation sub, pressure
up to 4193 psi to burst, continue fill
drillpipe at 10 BPM while bleeding air
out of SES.
12,042.0 12,042.0
11/15/2023
13:30
11/15/2023
15:00
1.50 COMPZN, WELLPR RURD P Blow down lines and rig down subs for
bleed manifold.
SIMOPS prep pits for displacement.
12,042.0 12,042.0
11/15/2023
15:00
11/15/2023
17:15
2.25 COMPZN, WELLPR DISP P PJSM and displace well to 9.6 NaCl @
500 GPM 3100 psi 8215 strokes
pumped.
SIMOPS blow down all lines and clean
drip pans.
12,042.0 12,042.0
11/15/2023
17:15
11/15/2023
17:30
0.25 COMPZN, WELLPR OWFF P Perform flow check well static. 12,042.0 12,042.0
11/15/2023
17:30
11/15/2023
18:00
0.50 COMPZN, WELLPR PULD P POOH laying down 5-7/8" drillpipe to
pipe shed. from 12,042' to 11,887' .
Monitor displacment on trip tank.
12,042.0 11,887.0
11/15/2023
18:00
11/16/2023
00:00
6.00 COMPZN, WELLPR PULD P POOH laying down 5-7/8" drillpipe to
pipe shed. from 11,887' to 8116' .
Monitor displacement on trip tank.
11,887.0 8,116.0
11/16/2023
00:00
11/16/2023
06:00
6.00 COMPZN, WELLPR PULD P Swap handling equipment to 4-1/2" and
continue POOH laying down 4-1/2"
drillpipe to pipe shed. from 8116' to
3030' . Monitor displacement on trip
tank.
8,116.0 3,030.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 38/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/16/2023
06:00
11/16/2023
09:30
3.50 COMPZN, WELLPR PULD P Continue POOH laying down 4-1/2"
drillpipe to pipe shed. from 3030' to 54'' .
Monitor displacement on trip tank.
3,030.0 54.0
11/16/2023
09:30
11/16/2023
10:30
1.00 COMPZN, WELLPR OTHR P Inspect and L/D Baker liner hanger
running tool as per Baker rep
54.0 0.0
11/16/2023
10:30
11/16/2023
14:00
3.50 COMPZN, WELLPR RURD P Clean and clear rig floor, Conduct
derrick inspection, service top drive,
Prep rig for RIH with 4.5" drillpipe from
derrick. Drain BOP stack, install 35'
mouse hole. Run 1 stand in mouse hole
to test laying down. Evaluate and decide
to RIH and lay down pipe.
0.0 0.0
11/16/2023
14:00
11/16/2023
18:00
4.00 COMPZN, WELLPR TRIP P Trip in hole with 4.5: drill pipe from
derrick.
0.0 11,887.0
11/16/2023
18:00
11/17/2023
00:00
6.00 COMPZN, WELLPR PULD P POOH laying down singles to the
pipeshed. 11,887' to 7000'.
11,887.0 7,000.0
11/17/2023
00:00
11/17/2023
06:00
6.00 COMPZN, WELLPR PULD P POOH laying down singles to the pipe
shed. 7,000' to 0'.
7,000.0 0.0
11/17/2023
06:00
11/17/2023
09:30
3.50 COMPZN, RPCOMP WWWH P Clean and clear rig floor rig up stack
washer, wash wear ring and BOP stack.
Pull wear ring as per FMC and wash
well head profile.
0.0 0.0
11/17/2023
09:30
11/17/2023
13:15
3.75 COMPZN, RPCOMP RURD P Rig up SLB upper completion running
equipment spools for TEC wire and
HYD line. Rig up Doyon casing running
equipment.
0.0 0.0
11/17/2023
13:15
11/17/2023
14:15
1.00 COMPZN, RPCOMP PUTB RIH with 4-1/2" 12.6# L80 HYD563
upper completions as per tally. HES self
orientating mule shoe, Locator shear
sub NOGO, Arsenal glass plug/Burst
5500 psi and landing nipple. from 0 to
200'
0.0 200.0
11/17/2023
14:15
11/17/2023
15:15
1.00 COMPZN, RPCOMP RURD P Make up SLB Gauge mandrel and
function test valve 3 x then pressure test
to 8500 PSI for 15 minutes.
200.0 200.0
11/17/2023
15:15
11/17/2023
21:00
5.75 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L80 HYD563
upper completions as per tally. From
200' to 4251'
200.0 4,251.0
11/17/2023
21:00
11/18/2023
00:00
3.00 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L80 HYD563
upper completions as per tally. From
4251' to 6835'
SOW = 105K
4,251.0 6,835.0
11/18/2023
00:00
11/18/2023
04:45
4.75 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L80 HYD563
upper completions as per tally. From
6835' to 10,512'
Filling every 10 joints
SOW = 101K
6,835.0 10,512.0
11/18/2023
04:45
11/18/2023
06:00
1.25 COMPZN, RPCOMP RURD P M/U SLB TRMAXX safety valve ,
function test and pressure test hydrualic
control line to 8500 psi for 15 minutes.
10,512.0 10,512.0
11/18/2023
06:00
11/18/2023
08:45
2.75 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L80 HYD563
upper completions as per tally. From
10,512' to 12,067'
Filling every 10 joints.
SOW = 100K
PUW = 129K
10,512.0 12,067.0
11/18/2023
08:45
11/18/2023
09:00
0.25 COMPZN, RPCOMP HOSO P Sting Baker shear collar locator into top
of liner, observe shear pins shear at
12,067' MD with 15K. Pick up 5' and
retag with 10K at 12,067' MD space out
2.1' from fully located.
12,067.0 12,067.0
11/18/2023
09:00
11/18/2023
09:45
0.75 COMPZN, RPCOMP PUTB P Pull from 12,067' to 11,940' L/D 4 joints
of tubing
12,067.0 11,940.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 39/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/18/2023
09:45
11/18/2023
10:45
1.00 COMPZN, RPCOMP HOSO P Make up pup joints , 9.72', 9.67' , 5.79' ,
3.9' M/U joint #293 on top of pup joints
and Run in to 12,011' .
Make up 2 piece landing joint and
hanger.
11,940.0 12,011.0
11/18/2023
10:45
11/18/2023
12:45
2.00 COMPZN, RPCOMP THGR P Make up TEC wire , HYD line through
hanger and pressure test to 5K.
Terminate the SSV control line around
hanger neck. Test SSV control line to
8500 psi for 15 minutes.
12,011.0 12,011.0
11/18/2023
12:45
11/18/2023
13:15
0.50 COMPZN, RPCOMP THGR P Drain BOP stack and RIH and land
hanger on depth 12065.01. Torque lock
down screws as per FMC.
12,011.0 12,065.0
11/18/2023
13:15
11/18/2023
14:00
0.75 COMPZN, RPCOMP PRTS P Fill BOP stack and close upper pipe
rams,Pressure test hanger seals to 250
PSI for 5 minutes and 4000 psi for 10
minutes.
12,065.0 12,065.0
11/18/2023
14:00
11/18/2023
15:00
1.00 COMPZN, RPCOMP RURD P Rig down TEC wire and HYD line
spools. Clean and clear SLB equipment
from rig floor.
12,065.0 12,065.0
11/18/2023
15:00
11/18/2023
15:30
0.50 COMPZN, RPCOMP RURD P Rig up lines and valves to set packer
pumping down tubing and IA.
12,065.0 12,065.0
11/18/2023
15:30
11/18/2023
17:30
2.00 COMPZN, RPCOMP PACK P Set HES TNT packer as per procedure.
Pump down tubing and pressure up to
3500 PSI with 23 strokes at 55 SPM and
hold for 30 minutes. Bleed tubing to
2500 PSI. pump down IA @ 10 SPM
and pressure up to 3850 psi and hold for
30 minutes. Bleed off tubing pressure to
shear SOV. Bleed off all pressure and
circulate down the IA at 2 BPM and 800
psi, taking returns up the tubing,
12,065.0 0.0
11/18/2023
17:30
11/18/2023
18:00
0.50 COMPZN, RPCOMP OWFF P Blow down and rig down lines for packer
set, while flow check well for 30
minutes.
0.0 0.0
11/18/2023
18:00
11/18/2023
19:45
1.75 COMPZN, RPCOMP PRTS P Back out landing joint and install BPV
with T-Bar, Pressure test BPV from
below to 2500 PSI for 15 minutes.
0.0 0.0
11/18/2023
19:45
11/18/2023
21:45
2.00 COMPZN, WHDBOP RURD P Flush all surface lines and equipment
with deep clean. Flush MPD equipment
and lines with deep clean. Blow down all
Mud pump lines, choke lines and MPD
equipment.
0.0 0.0
11/18/2023
21:45
11/18/2023
22:30
0.75 COMPZN, WHDBOP RURD P L/D landing joint , R/D bail extensions
and side door elevators.
0.0 0.0
11/18/2023
22:30
11/19/2023
00:00
1.50 COMPZN, WHDBOP RURD P PJSM and Remove riser, N/D RCD
equipment , mobilize frac tree to BOP
deck, nipple down BOP stack and HP
riser. Remove Fox hole and L/D.
0.0 0.0
11/19/2023
00:00
11/19/2023
06:00
6.00 COMPZN, WHDBOP NUND P Rig down RCD equipment mobilize frac
tree to BOP deck. Nipple down BOP
stack and HP riser, remove fox holes
and L/D. Remove mouse hole, rack
back and secure, mobilize low pressure
riser to BOP deck, R/B and secure. M/U
frac tree to adapter flange, stab frac tree
as per FMC rep. SLB terminate SSSV
HYD line and TEC wire in wellhead.
Initial readings from SGM before FP.
Tbg=2018.63 psi, 92.012° F.
IA=2019.91 psi, 92.025° F
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 40/40
CD4-536
Report Printed: 12/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/19/2023
06:00
11/19/2023
08:30
2.50 COMPZN, WHDBOP RURD P Torque tree and adapter nuts to spec
and test adapter void as per FMC rep,
R/U lines and equipment to freeze
protect and test tree. Continue top
rinsing pits. Shovel stompers and tires
on complexes. Prep pipe shed to move.
Drain centrifugal snails and remove
interconnect lines in pump room.
0.0 0.0
11/19/2023
08:30
11/19/2023
09:45
1.25 COMPZN, WHDBOP PRTS P Fill tree with diesel and pressure test to
250 psi low and 10,000 psi high for 15
minutes.
0.0 0.0
11/19/2023
09:45
11/19/2023
11:30
1.75 COMPZN, WHDBOP RURD P R/D test equipment , FMC pulled test
dart and BPV. R/U to freeze protect well.
0.0 0.0
11/19/2023
11:30
11/19/2023
12:00
0.50 COMPZN, WHDBOP SEQP P PJSM and pressure test surface lines
from LRS for freeze protect to 3000 psi.
0.0 0.0
11/19/2023
12:00
11/19/2023
13:30
1.50 COMPZN, WHDBOP FRZP P Freeze protect annulus with 103 Bbls
diesel @ 1.25 BPM, ICP = 262 psi, FCP
= 483 psi. taking returns to the CPU.
0.0 0.0
11/19/2023
13:30
11/19/2023
14:45
1.25 COMPZN, WHDBOP FRZP P U-tube diesel freeze protect, blow down
rig water and empty and rinse CPU.
0.0 0.0
11/19/2023
14:45
11/19/2023
16:15
1.50 COMPZN, WHDBOP SSSV P SLB release pressure on SSSV to close
valve, LRS pumped down tubing to 250
PSI and monitor tubing increase to 250
psi, valve not closed. Shut down
pumping and bleed pressure off tubing
resume pumping and pressure up to
2500 psi with tubing staying at 0 psi.
Valve closed.
0.0 0.0
11/19/2023
16:15
11/19/2023
18:00
1.75 DEMOB, MOVE RURD P Clear freeze protect lines to
Hydrocarbon truck. R/D freeze protect
and U-tube piping and equipment.
Remove extra annulus valves and
Flange off IA and OA, install gauges on
flangesOA/IA. Install tree cap
disconnect interconnect mud lines.
Finish blowing down rig water. Prepare
CPU to move. Warm up cold starts,
clean cellar/BOP deck of tools and
equipment for move. Disconnect MPD
lines on MPD deck.
Release rig at 18:00 hrs.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 11/19/2023
Page 1/1
CD4-536
Report Printed: 12/11/2023
Cement
Cement Details
Description
Conductor String Cement
Cementing Start Date
4/14/2023 15:15
Cementing End Date
4/14/2023 18:00
Wellbore Name
CD4-536
Comment
AFC used 3500 psi concrete.
Cement Stages
Stage # <Stage Number?>
Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return?Vol Cement …Top Plug? Btm Plug?
Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Conductor String Cement
Page 1/1
CD4-536
Report Printed: 12/11/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
10/12/2023 12:30
Cementing End Date
10/12/2023 15:22
Wellbore Name
CD4-536
Comment
Lined up on SLB cementing unit. SLB pumped water & pressure tested lines to 3500 psi.
Pumped 111.5 bbls of 10.5 ppg MudPush II at 4.5 bpm, 100 psi.
Dropped bottom plug.
Pumped 377 bbls of 11.0 ppg lead cement at 5.3 bpm, 359 psi.
Pumped 73.7 bbls of 15.8 ppg tail cement at 4.5 bpm, 308 psi.
Dropped top plug.
Pumped 20 bbls of fresh water at 7 bpm, 90 psi.
Lined up on rig pump.
Displaced with 10.5 ppg treated mud at 8 bpm, 812 psi. Slowed rate to 5 bpm, 570 psi. Bumped the plug with 362 bbls/3047 stks pressuring up to 1023 psi. Held
for pressure for 5 minutes. Bled off pressure, checked floats, good.
CIP 15:22 hrs.
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
54.0
Bottom Depth (ftKB)
2,630.0
Full Return?
Yes
Vol Cement …
82.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
8
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
7
P Pump Final (psi)
575.0
P Plug Bump (psi)
1,023.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
54.0
Est Btm (ftKB)
2,130.0
Amount (sacks)
1,101
Class
*NOT IN LIBRARY
Volume Pumped (bbl)
377.0
Yield (ft³/sack)
1.92
Mix H20 Ratio (gal/sack)
6.72
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
177.0
Thickening Time (hr)
5.45
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,130.0
Est Btm (ftKB)
2,630.0
Amount (sacks)
356
Class
G
Volume Pumped (bbl)
73.7
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.05
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
68.0
Thickening Time (hr)
4.23
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
CD4-536
Report Printed: 12/11/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
10/20/2023 00:30
Cementing End Date
10/20/2023 04:45
Wellbore Name
CD4-536
Comment
Cemented 9-5/8" intermediate 1 casing per SLB program. PJSM held with all personnel.
Lined up to cementing unit and pumped 6 bbls of water. Pressure tested lines to 4276 psi, good.
Pumped 75.2 bbls of 12.0 ppg MudPush at 5 bpm; 505 psi.
Dropped bottom plug.
Batched & pumped 165.9 of 15.8 ppg Tail cement at 5 bpm; 808 psi. Added cemnet to 20 bbls of cement.
Dropped top plug.
Pumped 20 bbls of fresh water at 5 bpm; 220 psi.
Lined up to rig pump & displaced cement with 10.8 ppg FWP mud. Pumped at 5 bpm until 5 bbls before bottom plug landed then slowed to 2.5 BPM for remainder
of job; ICP 55 psi; FCP 320 psi. Observed bottom plug bump & shear at 386.8 bbls pumped, 2.5 bpm; 211-413 psi. Bumped top plug with 548.9 bbls pumped at
2.5 bpm; 370-881 psi. Held pressure for 5 minutes. Bled off pressure. Pressure tested casing to 3,850 psi for 30 min. Bled off pressure, float held. CIP 04:25 hrs.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
6,090.0
Bottom Depth (ftKB)
7,845.0
Full Return?
No
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
5
P Pump Final (psi)
413.0
P Plug Bump (psi)
881.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Intermediate Cement
Fluid Description Estimated Top (ftKB)
6,090.0
Est Btm (ftKB)
7,845.0
Amount (sacks)
796
Class
G
Volume Pumped (bbl)
165.9
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
4.74
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
112.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
Page 1/1
CD4-536
Report Printed: 12/11/2023
Cement
Cement Details
Description
Intermediate String 2 Cement
Cementing Start Date
10/30/2023 11:00
Cementing End Date
10/30/2023 13:22
Wellbore Name
CD4-536
Comment
Lined up to cementers & flooded lines with 5 bbls of water. Pressure tested lines to 6500 psi. Batched & pumped 40 bbls of 12.0 ppg MudPush II at 3.8 bpm, 550-
420 psi. Dropped bottom dart. Batched & pumped 145 bbls of 15.8 ppg class G cement at 5-6 bpm, 455-253 psi. Dropped top dart. Pumped 20 bbls of water at 5
bpm, 75 psi. Swapped to rig pump and displaced cement with 9.5 ppg mud at 4.75-6 bpm, 243-1056 psi. Dropped BOZO plug with 160.2 bbls of mud pumped.
Did not see any pressure for lower wiper plug latch up. Observed top wiper plug latch up with 1737 psi. Bumped the plug with 364.3 bbls pumped, at 680 psi.
Pressured up to 1100 psi & held for 5 minutes. Bled off pressure and checked floats, good. CIP 13:22 hrs.
Cement Stages
Stage # 1
Description
Intermediate String 2
Cement
Objective Top Depth (ftKB)
9,020.0
Bottom Depth (ftKB)
12,390.0
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
6
P Pump Final (psi)
1,056.0
P Plug Bump (psi)
680.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Intermediate Cement
Fluid Description Estimated Top (ftKB)
9,020.0
Est Btm (ftKB)
12,390.0
Amount (sacks)
696
Class
G
Volume Pumped (bbl)
145.0
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
4.76
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
104.0
Thickening Time (hr)
6.10
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 2 Cement
SAMPLE TRANSMITTAL
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
CD4-536
12390 -20995
2 Boxes
SENT BY: M. McCRACKEN
l 1E)UC)L�
DATE: December 1, 2023
AIR BILL: N/A
CPAI: CPA12023120101
CHARGE CODE: N/A
NAME: CD4-536
NUMBER OF BOXES: 2 Boxes
UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY
OF THIS FORM TO:
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
RECEIVED:
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name:4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?CD4-536
Yes No
9. Property Designation (Lease Number):10. Field:
Colville Riv
Qannik Oil pool
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
20,995 1550 none none
Casing Collapse
Structural
Conductor
Surface 2,260.0
Intermediate 5,090.0
Production 4790, 11,080
Liner 9,210.0
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
4206.8 20,953.20 4206.3
30-Nov-23
20,958.08,900.1
4-1/2"
4,266.1
Halliburton TNT Packer, Baker SLZXP Liner
Top Packer, SLB TRMAXX-5E SSSV
7,839.0
2,630.0
12,380.0
Perforation Depth MD (ft):
7,839.0
none
4,685.0
4-1/2"
none
133
2,630.0
4,070.27-5/8"
20" x 34"
13-3/8"
133.0
9-5/8"8,150.0
5,020.0
133
2,412.6
3,467.8
Proposed Pools:
L-80"
TVD Burst
12,061.71
6890, 12,620
MD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380077, ADL384211, ADL380082, ADL388903,
ADL391587
223-079
P.O. Box 100360 Anchorage, AK 99510 -0360 5010320863
ConocoPhillips Alaska Inc.
AOGCC USE ONLY
11,590.0
Tubing Grade:Tubing MD (ft):
LTP @ 12,069.79' MD / 4045' TVD
Production Packer 11,926.7' MD/ 4034' TVD
SSSV @ 1575.9' MD / 1552' TVD
Perforation Depth TVD (ft):
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Length Size
Robert.g.blakney@cop.com
Robert Blakney
907-947-8498
Completion Engineer
Subsequent Form Required:
Suspension Expiration Date:
raam
owwwn s
2
66
t
___
c
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
11/21/2023
By Grace Christianson at 7:43 am, Nov 22, 2023
323-632
30-Nov-23
X
Fracture Stimulate
50-103-20863-00-00 SFD
DSR-11/22/23
CDW 11/27/2023
10-404
VTL 11/27/2023
SFD
SFD 11/27/2023*&:JLC 11/28/2023
Brett W. Huber, Sr.Digitally signed by Brett W. Huber,
Sr.
Date: 2023.11.28 13:28:32 -09'00'11/28/23
RBDMS JSB 113023
Section 1 - Affidavit 10 AAC 25.283 (a)(1)
Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators
within one-half mile radius of the current or proposed wellbore trajectory have been provided
notice of operations in compliance with 20 AAC 25.283(a)(1).
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Table 1: Wells within 1/2 miles (2)(C)
Distance FEL, ft Township Range Section Meridian Well Name API Well Type Status Field Name Well in Frac Port 1/2 mi Buffer Open Interval in Frac Port 1/2 mi Buffer
432.5 T11N R4E 24 Umiat CD4-539 501032086300 INJ ACTIVE NARWHAL YES YES
1488.5 T11N R5E 29 Umiat CD4-594 501032080700 INJ ACTIVE NARWHAL YES YES
2716 T11N R5E 33 Umiat CD4-595 501032077800 PROD ACTIVE NARWHAL YES YES
CD4-597 501032083900 INJ ACTIVE NARWHAL YES YES
CD4-594PH1 501032080770 EXPEND PA NARWHAL YES Well is P&A
CD4-595PH 501032077870 EXPEND PA NARWHAL YES Well is P&A
CD4-298PB1 501032062370 EXPEND PA NANUQ YES Well is P&A
CD4-301 501032055700 PROD PA NANUQ KUPARUK YES Well is P&A
CD4-586 501032085700 PROD ACTIVE NARWHAL NO NO
CD4-588 501032085300 PROD ACTIVE NARWHAL NO NO
CD4-298 501032062300 PROD ACTIVE NANUQ
CD4-301A 501032055701 PROD PA NANUQ KUPARUK
CD4-301B 501032055702 PROD ACTIVE NANUQ KUPARUK
CD2-77 501032062900 PROD ACTIVE ALPINE
CD4-03 501032064100 INJ ACTIVE ALPINE
CD4-05 501032055800 PROD ACTIVE ALPINE
CD4-07 501032055300 PROD ACTIVE ALPINE
CD4-12 501032041401 INJ ACTIVE ALPINE
CD4-12PB1 501032041470 EXPEND PA ALPINE
CD4-16 501032053500 PROD ACTIVE ALPINE
CD4-17 501032053400 INJ ACTIVE ALPINE
CD4-208 501032051700 INJ PA NANUQ
CD4-208A 501032051701 PROD ACTIVE ALPINE
CD4-208AL1 501032051760 PROD ACTIVE ALPINE
CD4-208APB1 501032051771 EXPEND PA ALPINE
CD4-208PB1 501032051770 EXPEND PA NANUQ
CD4-209 501032053200 INJ ACTIVE NANUQ
CD4-210 501032053300 PROD PA NANUQ
CD4-210A 501032053301 PROD PA ALPINE
CD4-210APB1 501032053370 EXPEND PA ALPINE
CD4-210B 501032053302 PROD ACTIVE ALPINE
CD4-211 501032053800 PROD ACTIVE NANUQ
CD4-211L1 501032053860 PROD ACTIVE NANUQ
CD4-211L1-01 501032053861 PROD ACTIVE NANUQ
CD4-213 501032054000 INJ PA NANUQ
CD4-213A 501032054001 INJ PA ALPINE
CD4-213B 501032054002 INJ ACTIVE ALPINE
CD4-213BPB1 501032054070 EXPEND PA ALPINE
CD4-213BPB2 501032054071 EXPEND PA ALPINE
CD4-214 501032053700 INJ ACTIVE NANUQ
CD4-214L1 501032053760 INJ ACTIVE NANUQ
CD4-215 501032053900 PROD ACTIVE NANUQ
CD4-215L1 501032053960 PROD ACTIVE NANUQ
CD4-23 501032062100 PROD ACTIVE ALPINE
CD4-23PB1 501032062170 EXPEND PA ALPINE
CD4-23PB2 501032062171 EXPEND PA ALPINE
CD4-24 501032060200 INJ ACTIVE ALPINE
CD4-24PB1 501032060270 EXPEND PA ALPINE
CD4-24PB2 501032060271 EXPEND PA ALPINE
CD4-25 501032060800 PROD ACTIVE ALPINE
CD4-25L1 501032060860 PROD ACTIVE ALPINE
CD4-25PB1 501032060870 EXPEND PA ALPINE
CD4-26 501032060000 INJ ACTIVE ALPINE
CD4-27 501032064400 INJ ACTIVE ALPINE
CD4-27PB1 501032064470 EXPEND PA ALPINE
CD4-27PB2 501032064471 EXPEND PA ALPINE
CD4-27PB3 501032064472 EXPEND PA ALPINE
CD4-289 501032069700 INJ ACTIVE NANUQ
CD4-290 501032067400 PROD ACTIVE NANUQ
CD4-291 501032067200 INJ ACTIVE NANUQ
CD4-291PB1 501032067270 EXPEND PA NANUQ
CD4-292 501032066900 PROD ACTIVE NANUQ
CD4-302 501032054500 INJ ACTIVE NANUQ KUPARUK
CD4-304 501032055500 PROD ACTIVE NANUQ KUPARUK
CD4-304PB1 501032055570 EXPEND PA NANUQ KUPARUK
CD4-306 501032055000 INJ ACTIVE NANUQ KUPARUK
CD4-318 501032051900 PROD PA NANUQ KUPARUK
CD4-318A 501032051901 PROD ACTIVE NANUQ KUPARUK
CD4-318PB1 501032051970 EXPEND PA NANUQ KUPARUK
CD4-319 501032051600 INJ ACTIVE NANUQ KUPARUK
CD4-320 501032053100 PROD ACTIVE NANUQ KUPARUK
CD4-320PB1 501032053170 EXPEND PA NANUQ KUPARUK
CD4-321 501032053600 INJ ACTIVE NANUQ KUPARUK
CD4-322 501032055100 INJ ACTIVE NANUQ KUPARUK
CD4-499 501032081000 PROD ACTIVE QANNIK
CD4-93 501032069000 PROD PA ALPINE
CD4-93A 501032069001 PROD ACTIVE ALPINE
CD4-96 501032067300 PROD PA ALPINE
CD4-96A 501032067301 PROD ACTIVE ALPINE
CD4-96APB1 501032067370 EXPEND PA ALPINE
NANUQ 3 501032036500 EXPLOR PA NANUQ
NANUQ 5 501032041400 EXPLOR PA ALPINE
Wells within 1/2 mile buffer of well track
* Data from SDE layer:
AK_WELL_BOTTOM_TD_ATDB_DD83
SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3)
There are no freshwater aquifers or underground sources of drinking water within a one-half
mile radius of the current or proposed wellbore trajectory.
See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine
Oil Pool: Enhanced Recovery Project, which states “No underground sources of drinking water
(“USDWs”) exist beneath the permafrost in the Colville River Unit area.”
SECTION 4 – PLAN FOR BASELINE WATER SAMPLING FOR
WATER WELLS 20 AAC 25.283(a)(4)
There are no water wells located within one-half mile of the current or proposed wellbore
trajectory and fracturing interval. A water well sampling plan is not applicable.
SECTION 5 – DETAILED CEMENTING AND CASING INFORMATION
20 AAC 25.283(a)(5)
All casing is cemented and tested in accordance with 20 AAC 25.030.
See Wellbore schematic for casing details.
Producer SFD
SECTION 6 – ASSESSMENT OF EACH CASING AND CEMENTING
OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE
WELL 20 AAC 25.283(a)(6)
Casing & Cement Assessments:
13 & 3/8” casing cement pump report on 10/12/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with
11ppg DeepCRETE cement lead, followed by 15.8 ppg class G cement displaced with 10.5
ppg treated water-based mud. Full returns were seen throughout the job. The plug bumped at
1023 psi and the floats were checked and they held.
9 & 5/8” casing cement pump report on 10/20/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 15.8
ppg class G cement, displaced with 10.8 ppg WBM. The plug bumped at 881 psi and the floats
were checked and they held.
The 7 & 5/8” casing cement report on 10/30/2023 shows that the job was pumped as designed,
indicating competent cementing operations. The cement job was pumped with 15.8 ppg class
G cement. Full returns were seen throughout the job. The plug bumped at 1100 psi and the
floats were checked and they held.
Summary
All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone
penetrated by the well is isolated.
Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has
determined that this well can be successfully fractured within its design limits.
SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO
PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE
WELL 20 AAC 25.283(a)(7)
On 10/14/2023 the 13-3/8” casing was pressure tested to 2,600 psi for 30 minutes
On 10/20/2023 the 9-5/8” casing was pressure tested to 3,850 psi for 30 minutes.
On 10/31/2023 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes.
On 11/18/2023 the 4-1/2” tubing was pressure tested to 3,500 psi for 30 minutes.
On 11/18/2023 the 7-5/8” casing by 9-5/8” by 4.5 tubing annulus was pressure tested to
3,850 psi for 30 minutes.
AOGCC Required Pressures [all in psi]
Maximum Predicted Treating Pressure (MPTP) 6,125
Annulus pressure during frac 3,500
Annulus PRV setpoint during frac 3,600
7-5/8" Annulus pressure test 3,850
4-1/2" Tubing pressure Test 3,500
Electronic PRV 7,125
Highest pump trip 6,625
6,125
SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE
WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC
25.283(a)(8)
Table 2: Wellbore pressure ratings
Size Weight, ppf Grade API Burst, psi API Collapse, psi
13 & 3/8” 68 L-80 5,050 2,260
9 & 5/8” 47 L-80 5,750 3,090
7 & 5/8” 29.7 L-80 6,890 4,790
7 & 5/8” 39 P-110S 12,620 11,700
4.5” 12.6 L-80 8,430 7,500
4.5” 12.6 P-110S 11,590 9,210
Stimulation Surface Rig-Up
Alpine 10K Frac Tree
SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING
ZONES 20 AAC 25.283(a)(9)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that the fracturing zone consists of Cretaceous Brookian “Narwhal” Topset
Sands. The Narwhal interval is approximately 60’ TVD thick at the heel of the lateral, thickening
to >300’ TVD at the toe. The Narwhal reservoir is a very fine-grained quartz and lithic rich sand,
interbedded with mudstone and siltstone, with a coarsening upward log profile. Top Narwhal
was intersected at 12,700’ MD, -4017’ TVDSS. The estimated fracture gradient for the Narwhal
reservoir is 10.9 ppg.
The overlying confining zone consists of greater than 1350’ TVD of Seabee Formation
(dominantly mudstones beginning at top of C-30, 2680’ MD, -2373’ TVDSS) and approximately
240’ TVD of Albian K3 (dominantly siltstones). The estimated fracture gradient for the Seabee
is 16-17 ppg and for the Albian K3 14.2 ppg.
The underlying confining zone consists of approximately 250’ TVD of Albian mudstones and
siltstones, based on nearby well control (CD4-595PH) and was not penetrated in the CD4-536
wellbore. The estimated fracture gradient for this interval is 16-17 ppg.
SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
The plat shows the location and orientation of each well that transects the confining zone.
ConocoPhillips has formed the opinion, based on following assessments for each well and
seismic, well, and other subsurface information currently available that none of these wells will
interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the
proposed wellbore trajectory.
Casing & Cement assessments for all wells that transect the confining zone:
CD4-539: The 7 &5/8” Intermediate 2 liner was cemented on 9/16/2023. The cement job was
pumped with 15.8 ppg class G cement. The plug bumped at 1160 psi and the floats were
checked and they held. Full returns were seen throughout the job. A Slim Cement Mapping
Tool (SCMT) log was run on Oct 1st, 2023 and the top of good cement is at 8,600 ftMD.
CD4-597: The 7” Intermediate 2 liner was cemented on 8/31/2022. The cement job was
pumped with 13 ppg Class G cement lead and 15.8 ppg class G cement tail. The plug bumped
at 1100 psi and the floats were checked and they held.
A Sonic Scope cement log was run on September 12th, 2022 and the top of good cement is at
9,850 ftMD.
CD4-595: The 7” intermediate 2 liner was cemented on 01/25/2019. The primary cement job
was pumped with 13.5 ppg Class G cement lead and 15.8 ppg class G cement tail. The plug
bumped and floats held during the job, with no losses to formation. A Slim Cement Mapping
Tool (SCMT) log was run on 05/17/2019 and the top of good cement is at 12,300 ftMD.
CD4-595 PH1: CD4-595 PH1 was plugged and abandoned per state regulations on
01/13/2019.
CD4-594: The 7” intermediate 2 liner was cemented on 11/24/2019. The primary cement job
was pumped with 13.0 ppg Class G cement lead and 15.78 ppg class G cement tail. The plug
bumped and floats held during the job, with no losses to formation. A Slim Cement Mapping
Tool (SCMT) log was run on 12/12/2019 and the top of good cement is at 13,353 ftMD.
CD4-594 PH1: CD4-594 PH1 was plugged and abandoned per state regulations on
11/10/2019.
Wells that do not transect the confining zone:
CD4-298 PB1: The wellbore was targeting Nanuq, deeper than the confining zone of K3 for
Narwhal. It was plugged back with class G cement per state regulations on 12/13/2010.
CD4-301: This well is targeting Nanuq Kuparuk, deeper than Narwhal. It has been plugged and
abandoned per state regulations on 12/20/2007.
SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL
DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE
CONFINING ZONES 20 AAC 25.283(a)(11)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that one fault or fracture system transected the confining zone within one
half mile radius of the wellbore trajectory for CD4-536. The fault intersected the CD4-536 well
path at 6448’ MD and was interpreted from seismic data prior to drilling. The fault was
encountered far above the reservoir interval in the overlying Seabee Formation and interpreted
as a single plane with 60-90’ of throw. Within one half mile radius of the wellbore trajectory for
CD4-539, the fault was also encountered in the CD4-539 at 6,460’ MD, CD4-594 at 6297’ MD,
CD4-595 at 6630’ MD, CD4-597 at 6745’ MD, CD4-586 at 6155’ MD, and CD4-588 at 6527’
MD. No losses were seen in any of the other wells in this fault. The CD4-536 also encountered
a small fault, 10-15’ throw, along the lateral at 17,020’ MD in the reservoir section. No losses
were seen when crossing this fault. We adjusted the CD4-536 frac sleeve and packer
placement to put a packer near the observed fault at 17.020’ MD.
Fracture gradients within the top seal intervals would not be exceeded during fracture
stimulation and would therefore confine injected fluids to the pool. CPAI has formed the
opinion, based on seismic, well, and other subsurface information currently available that the
apparent faults will not interfere with containment.
We do not expect any of our hydraulic fractures to intersect the overburden fault within the half
mile radius of this wellbore.
If there are indications that a fracture has intersected a fault during fracturing operations,
ConocoPhillips will go to flush and terminate the stage immediately.
Wellbore fault intersections that may transect the confining zones within a
half mile radius of the CD4-536 wellbore.
Well Name
Fault
Depth MD
(ft)
Fault Depth
TVDSS (ft)
Fault Vertical
Displacement
(ft)
Fluid
Losses
(bbls/hr)
CD4-536 6448 -3197 60-90 0
CD4-536 17020 -4094 10-15 0
CD4-539 6460 -3133 60-90 0
CD4-586 6155 -3158 60-90 0
CD4-588 6527 -2994 60-90 0
CD4-594 6297 -2888 60-90 0
CD4-595 6630 -2814 60-90 0
CD4-597 6745 -3162 60-90 0
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
CD4-536 was completed in 2023 as a horizontal injector in the Narwhal formation. The well
was completed with a 4.5” tubing upper completion and a 4.5” liner with 22 dart actuated sliding
sleeves lower completion. The 1st stage will be pumped with initially dropping dart to shift
sleeve opened, after that a dart will be dropped to open the next stage and isolate the stage
below. This will be repeated for stages 2-22.
Proposed Procedure:
Halliburton Pumping Services:
1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition
to identify any preexisting conditions.
2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus
are filled with a freeze protect fluid to 1,500’ TVD.
3. Pressure test the rig installed frac tree to 10,000 psi.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU ~ 20 clean insulated Frac tanks, with a berm surrounding the tanks that can
hold a single tank volume plus 10%. Load tanks with 100º F seawater (approx. 2,000
barrels are required for each stage with breakdown, maximum pad and pumping
down the next ball. (450 bbls usable volume per tank).
6. MIRU HES Frac Equipment.
7. PT Surface lines to 8,500 psi using a Pressure test fluid.
8. Test IA Pop off system to ensure lines are clear and all components are functioning
properly.
9. Bring up pumps and increase annulus pressure from 2,500 psi to 3,500 psi as the
tubing pressures up.
10. Pump the 300 bbl breakdown stage (30# Delta) according to the attached excel HES
pump schedule. Bring pumps up to maximum rate of 25 BPM as quickly as possible,
pressure permitting. Ensure sufficient volume is pumped to load the well with Frac
fluid, prior to shut down.
11. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates.
12. Pump the 22 stage Frac job by following attached HES schedule @ ~25 bpm with a
maximum expected treating pressure of 4,500 psi.
13. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to
complete following the flush.
14. Well is ready for Post Frac well prep/production tree installation, coil clean out, and
flowback (Slickline and CTU).
g
f4,500 p
SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY
PLAN 20 AAC 25.283(a)(13)
Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will be turned over to
production for initial clean up production before conversion to injection
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________COLVILLE RIVER UNIT CD4-536
JBR 12/05/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
The pressure test went very well over all. We observed minor leaking around one of the lower #3 ram operators going back to
the accumulator. Once the test was finished they changed both of them out with new ones and retested. Passed test. I went
back in the morning to verify. All LEL and H2s alarms tested well. Accumulator bottle precharge is 36@1000 psi. Tested
everything with 5-7/8" test joint.
Test Results
TEST DATA
Rig Rep:Johnny Newman/ ArchiOperator:ConocoPhillips Alaska, Inc.Operator Rep:Rick Bjorhus/ Kenny Hardin
Rig Owner/Rig No.:Doyon 26 PTD#:2230790 DATE:10/14/2023
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopJDH231014154106
Inspector Josh Hunt
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 14
MASP:
1549
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
16 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 18-3/4" 5M P
#1 Rams 1 3-1/2"x6-5/8"P
#2 Rams 1 Blind/Shear P
#3 Rams 1 3-1/2"x6-5/8"FP
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3-1/8" 5M P
HCR Valves 2 3-1/16"& 3-1/P
Kill Line Valves 2 3" & 3-1/16" P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3050
Pressure After Closure P1700
200 PSI Attained P13
Full Pressure Attained P92
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P10@3800
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P14
#1 Rams P14
#2 Rams P15
#3 Rams P15
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
99
9 999
9
9
9FP
leaking around one of the lower #3 ram operators
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
700 G Street
Anchorage, AK, 99501
Re: Coville River Field, Qannik Oil Pool, CRU CD4-536
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-079
Surface Location: 2200 FSL, 432 FEL, Sec 24, Twn 11 N, Rg 4 E
Bottomhole Location: 549 FSL, 2738 FEL, Sec 33, Twn 11 N, Rg 5 E
Dear Mr.Brillon:
Enclosed is the approved application for the permit to drill the abovereferenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCCreserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or anAOGCCorder, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
-HVVLH&KPLHORZVNL
Commissioner
DATED this___ dayof6HSWHPEHU2023.29
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2023.09.29
14:00:29 -08'00'
1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address:6. Proposed Depth: 12. Field/Pool(s):
MD: 20,998 TVD: 4221
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date:
10/1/2023
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
594' to ADL393167
4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 73.5 15. Distance to Nearest Well Open
Surface: x-377809 y- 5957334 Zone- 4 18.9 to Same Pool: 97.4' to CD4-595
16. Deviated wells:Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 90 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42"20" 94.0 H-40 Welded 120 0 0 135 135
16"13.375" 68.0 L-80 Hyd563 2750 0 0 2645 2417
12.25" 9.625" 47.0 T-95 Hyd563 7861 0 0 7861 3471
8.5" x 9.5"7.625" 29.7 / 39.0 L-80 / P-110S Hyd523 4578 7775 3449 12353 4057
6.5"4.5" 12.6 P-110S Hyd563 6392 12203 4057 20998 4221
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned?Yes No
20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Justin Cremer
Chris Brillon Contact Email:Justin.Cremer@conocophillips.c
Engineering Manager Contact Phone:907-231-7426
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Perforation Depth MD (ft):
Uncemented liner w/ frac sleeves
Effect. Depth MD (ft):Effect. Depth TVD (ft):
Conductor/Structural
Authorized Title:
Authorized Signature:
Production
Liner
Intermediate
Authorized Name:
LengthCasing Cement Volume MDSize
Plugs (measured):
(including stage data)
10 yds
1078sx 11 ppg & 334sx 15.8 ppg
747sx 15.8 ppg Class G
2148, 2485, 640, 1247, 640
18. Casing Program:Top - Setting Depth - BottomSpecifications
1969
Total Depth MD (ft):Total Depth TVD (ft):
59-52-180
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
747sx 15.8 ppg Class G
1549
2416 FSL, 1557 FEL, Sec 29, Twn 11 N, Rg 5 E
549 FSL, 2738 FEL, Sec 33, Twn 11 N, Rg 5 E
LONS 97-007
P.O. Box 100360 Anchorage, Alaska, 99510-0360
ConocoPhillips
2200 FSL, 432 FEL, Sec 24, Twn 11 N, Rg 4 E ADL380077, ADL384211, ADL380082, ADL388903,
ADL391587
CD4-536
Narwhal Undefined Oil
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.
s N
ype of W
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1b
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Class:
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s
s
h
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0
o
:
well is p
G
S
S
20 A
S S
S
s No s No
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E
S
s No
s
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 9:14 am, Sep 01, 2023
Diverter variance granted per 20 AAC 25.035(h)(2) -A.Dewhurst
CRU
X
Colville River Unit
DSR-9/1/23VTL 09/29/2023
50-103-20863-00-00223-079
A.Dewhurst 12SEP23
Collville River/Qannik Oil Pool
Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig
Annular preventer test to 2500 psig
Waiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 extension attached
Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available.
Results of Sonic required to verify competent cement behind casing.
*&:
Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2023.09.29 14:00:49 -08'00'
ϰͲϱϯϲ
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
March 2, 2023
Mr. Luke Lawrence
Wells Manager
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Re: Docket Number: OTH-21-018
CPAI Rotary Rig BOPE Test Frequency
Dear Mr. Lawrence:
By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of
the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test
blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas
Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope.
OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25,
2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6,
2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance
Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on
February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of
the CPAI-operated rigs during 2022 in considering the requested continuance.1
During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate
in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21-
day intervals.2
CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is
approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions:
- The pilot test duration is for ONE year from the approval date of this letter, subject to
potential extension and expansion to include other CPAI operated rigs with at least 3
months of continuous rig work and AOGCC review of a rig’s BOPE system reliability.
1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the
interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for
allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of
component failures during BOPE testing by replacing components that indicate suspect integrity before those
components fail during testing.
2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre-
determined time intervals while drilling specific sections in an ultra-extended reach well.
Docket Number: OTH-21-018
March 2, 2023
Page 2 of 2
- CPAI must continue to implement the BWM program as approved by AOGCC.
- Development drilling wells only are included in this approval.
- The initial test after rigging up BOPE to drill a well must be to the rated working pressure
as provided in API Standard 53.
- CPAI is encouraged to take advantage of opportunities to test.
- CPAI must adhere to original equipment manufacturer recommendations and replacement
parts for BOPE.
- Requests for extensions beyond 21 days must include justification with supporting
information demonstrating the additional time is necessary for well control purposes or to
mitigate a stuck drill string.
- 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to
witness.
If you have questions regarding this, please contact Jim Regg at (907) 793-1236.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
cc: Greg Hobbs (CPAI)
Mike Kneale (CPAI)
Victoria Loepp (AOGCC)
AOGCC Inspectors (email)
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.02 11:09:23
-09'00'
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
August 23rd, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill CD4-536
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well from the CD4 drilling pad. The intended spud
date for this well is October 1st, 2023. The intended rig used to drill the well is Doyon Rig 26.
CD4-536 is planned to be a horizontal Narwhal sand producer. CD4-536 will be the third producer in the Narwhal sand.
The 16” surface hole will TD above the C-30 sand and then 13-3/8” casing will be set and cemented to surface.
The intermediate hole will be drilled in two sections to mitigate issues with formation instability over the long interval. The 12-1/4”
intermediate #1 section will be drilled to below the C-10 sand and landed at an inclination of ~82°. A 9-5/8” casing string will be set and
cemented from TD to secure the shoe and cover 250’ TVD (which is greater than 500’MD) above the shoe.
The second intermediate will be drilled with a 8-1/2” x 9-1/2” under-reamed steerable drilling assembly, ultimately landing 15’ TVD above
the Narwhal sand at an inclination of ~82°. A 7-5/8” liner string will be set and cemented from TD to secure the shoe and cover 1500’ MD
above top of uppermost hydrocarbon bearing zone, providing sufficient isolation and reducing chance of losses during the cementing job due
to weak formations. Offset wells CD4-595, CD4-594, CD4-597, CD4-588 and CD4-586 have been approved by AOGCC on same cement
design. It is also included in the ERIO 6 application.
The production interval will be comprised of a 6-1/2” horizontal hole that will be geo-steered in the Narwhal sand. The well will be
completed as a stimulated producer with 4-1/2” liner with frac sleeves and packers and tied back to surface with a 4-1/2” tubing upper
completion string. The well will be tied into exisiting CD4 facilities. After well completion the well will by hydraulically fractured.
It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h) (2) is granted for well CD4-536. At CD4, there has not
been a significant indication of shallow gas hydrates through the surface hole interval.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this
application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)
and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact:
Justin Cremer, (907) 231-7426 & Justin.Cremer@conocophillips.com,
or
Chris Brillon , (907) 265-6120 & Chris.l.Brillon@conocophillips.com
Sincerely, cc:
CD4-536 Well File / Jenna Taylor ATO 1560
David Lee ATO 1726
Chris Brillon ATO 1548
Justin Cremer Andy Mack Kuukpik
Drilling Engineer
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
CD4-536
AOGCC Application for Permit to Drill Document
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) ................................................................................ 2
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ................................................... 2
3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) .......... 2
4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) ................................... 3
5. Procedure for Conducting Formation Integrity Tests
(Requirements of 20 AAC 25.005 (c)(5)) ......................................................................................... 4
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ............................. 4
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)).................................... 4
8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .............................................. 5
9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ..... 6
10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .................................................... 6
11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................... 6
12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) .............................................. 6
13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) .................................... 7
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7
(Requirements of 20 AAC 25.005 (c)(14)) ....................................................................................... 8
15. Attachments ............................................................................................................. 8
Attachment 1 Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Property Plat
Attachment 5 Directional Plan CD4-536
Attachment 6: Wellhead Schematic
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as CRU CD4-536.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface (CD4-536 Slot) 2200’ FSL, 432’ FEL, Sec 24, T11N, R4E
NAD 27
Northings: 5956936
Eastings: 378531
RKB Elevation 73.5’ AMSL
Pad Elevation 19’ AMSL
Location at Productive Horizon (Heel) 2416’ FSL, 1557’ FEL, Sec 29, T11N, R5E
NAD 27
Northings: 5952128
Eastings: 386865
Measured Depth, RKB: 12,578
Total Vertical Depth, RKB: 4,084’
Total Vertical Depth, SS: 4,011’
Location at Total Depth (Toe) 549’ FSL, 2738’ FEL, Sec 33, T11N, R5E
NAD 27
Northings: 5944922
Eastings: 390877
Measured Depth, RKB: 20,998’
Total Vertical Depth, RKB: 4,221’
Total Vertical Depth, SS: 4,134’
Requirements of 20 AAC 25.050(b)
Please see Attachment 5: CD4-536 wp05 Directional Plan
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3))
Please reference BOP and diverter schematics on file for Doyon 26.
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4))
The following shows the calculation results of anticipated surface pressure (ASP) while drilling this well:
Casing Size
(in)
Casing Set Depth
MD/TVD (ft)
Fracture
Gradient
(ppg)
Pore
Pressure
(psi)
ASP Drilling
(psi)
20 135 / 135 10.9 50 63
13-3/8 2,645 / 2,417 14.4 1,052 1,175
9-5/8 7,862 / 3,471 14.2 1,522 1,509
7-5/8 12,353 / 4,068 14.6 1,916 1,549
4-1/2 20,998 / 4,221 15.0 1,969 N/A
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a
gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to
the surface as follows:
1) ASP = [(FG x 0.052) - 0.1] x D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb/gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP – (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
(A) ASP Calculations Per Interval
1. Drilling Below 20” Conductor:
ASP = [(FG x 0.052) – 0.1] x D
= [(10.9x 0.052) – 0.1] x 135 = 63psi
OR
ASP = FPP – (0.1 x D)
= 1,052 – (0.1 x 2,417) = 810 psi
2. Drilling Below 13-3/8” Surface Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(14.4 x 0.052) – 0.1] x 2,417’ = 1,568 psi
OR
ASP = FPP – (0.1 x D)
= 1,522 – (0.1 x 3,471’) = 1,175 psi
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
3. Drilling Below 9-5/8” Intermediate 1 Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(14.2 x 0.052) – 0.1] x 3,471 = 2,215 psi
OR
ASP = FPP – (0.1 x D)
= 1,916 – (0.1 x 4,068) = 1,509 psi
4. Drilling Below 7-5/8” Intermediate 2 Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(14.6 x 0.052) – 0.1] x 4,068 = 2,682 psi
OR
ASP = FPP – (0.1 x D)
= 1,969 – (0.1 x 4,207) = 1,549 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any hydrates nor gas zones.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata,
lost circulation zones, and zones that have a propensity for differential sticking;
Please see Attachment 2 - Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c)(5))
Drill out casing or liner shoe and perform LOT or FIT in accordance with the COP ERD LOT / FIT
procedure that ConocoPhillips Alaska has on file with the Commission.
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing Program: Specifications Top Bottom Cement Quantity, sacks
Hole Casing Weig
ht
Grade Coup
ling
Length MD TVD MD TVD
42" 20" 94.0 H-40 Weld
ed
120 0 0 135 135 10 yds
16" 13.375" 68.0 L-80 H563 2748 0 0 2,645 2,417 1078sx 11 ppg & 334sx 15.8
ppg
12.25" 9.625" 47.0 T-95 H563 8150 0 0 7,861 3,471 747sx 15.8 ppg Class G (TOC
250’TVD above casing shoe)
8.5” x
9.5”
7.625” 29.7/
39.0
L-80/
P-110S
H523 4895 7,775 3449 12,353 4,068 747sx 13ppg ext. lead, 239sx
15.8 ppg Class G (TOC
1500’MD above K3 sand)
6.5" 4.5" 12.6 P-110S H563 8,605 12,203 3995 20,998 4,221 Uncemented liner w/ frac
sleeves
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7))
CPAI requests a variance to the diverter requirement under 20 AAC 25.035 (h)(2) be granted.
At CD4, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval.
There are 3 previously drilled wells (CD4-208A, CD4-292, CD4-597) within 500’ and 6 previously drilled wells
(CD4-302, CD4-499, CD4-209) within 1000’ of the proposed CD4-536 surface shoe location. None of these wells
encountered any significant indication of shallow gas or gas hydrates.
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate
#1
Intermediate
#2
Producti
on
Hole Size in 16 12-1/4 8-1/2 x 9-1/2 6-1/2
Casing
Size in 13-3/8 9-5/8 7-5/8 4-1/2
Density ppg 10.5 10.8 9.0 8.0
PV cP 9 – 10 10-15 10-15 12-17
YP
lb./
100
ft2
45 – 50 25 – 40 25 – 30 10-15
Initial
Gels
lb./
100
ft2
46 14 15 7
10
Minute
Gels
lb./
100
ft2
48 15 25 8
API Fluid
Loss
cc/
30
min
< 10 < 10 < 10 NA
pH 9.5-10.8 9.5-10 9.5-10 NA
Surface Hole:
The Surface interval will be drilled with a mixed-metal oxide freshwater drilling fluid (DRILPLEX WBM).
Keep flow line viscosity at r 200 sec/qt while drilling and running casing. Reduce viscosity prior to
cementing. Maintain mud weight 10.0ppg through the base of Permafrost and increase to 10.5 ppg prior
to TD. Control LGS using solids control system and dilutions where necessary.
Intermediate #1:
The Intermediate 1 interval will be drilled with a fresh water gel / polymer drilling fluid (FWP WBM).
Ensure good hole cleaning by maximizing fluid annular velocity and rotary speed. Maintain mud weight at
10.0ppg for shallow instability. Good filter cake quality, hole cleaning and maintenance of low gravity drill
solids (by diluting as required) will all be important in maintaining good hole conditions.
Intermediate #2:
The Intermediate 2 interval will be drilled with a fresh water gel / polymer drilling fluid (FWP WBM).
Ensure good hole cleaning by maximizing fluid annular velocity and rotary speed. Maintain mud weight at
9.6 ppg for instability. MPD may be used to prevent cycling on the formation. Good filter cake quality, hole
cleaning and maintenance of low gravity drill solids (by diluting as required) will all be important in
maintaining good hole conditions.
Production Hole:
The Production interval will be drilled with an inhibitive mineral oil based drilling fluid (VersaClean).
Ensure good hole cleaning by maximizing fluid annular velocity. Good filter cake quality, hole cleaning,
and maintenance of low gravity drill solids (by diluting as required) will all be important in maintaining
good hole conditions. Mitigate wellbore instability with MPD targeting ~10 ppg EMW on connections.
Please reference pit diagram on file for Doyon 26. All drilling fluid practices will be in accordance with
appropriate regulations stated in 20 AAC 25.033.
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11))
N/A - Application is not for an offshore well.
12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13))
The proposed drilling program is listed below. Please refer to Completion Schematic.
1. Install landing ring on conductor on existing 20” conductor. Conductor set at 135’ RKB.
2. Move in / rig up Doyon Rig 26 on conductor.
3. Pick up 5-7/8” DP and prepare surface drilling fluid.
4. Spud and directionally drill 16” hole to casing point at +/-2,645’ MD / 2,417’ TVD as per directional plan. Run
MWD / LWD logging tools (LMWD Program: GR/DIR) in drill string as required for directional monitoring
and formation data gathering.
5. Run and cement new 13-5/8" 68.0# L-80 H563 casing to surface. Adequate excess cement will be pumped to
ensure cement returns the surface.
6. Install wellhead and test to 1000 psi. Nipple up BOPE with the following equipment/configuration:
a. 18-5/8” Annular / Upper 4-1/2” x 7-5/8” VBR / Blind/Shear Ram / Lower 4-1/2” x 7-5/8” VBR
7. Test BOPE to 250psi low / 5,000psi high. Test annular to 250psi low / 3,500psi high. (Provide 48 hr. AOGCC
notice)
a. This test pressure meets the requirements for the 21 day pressure testing cycle which requires an
initial pressure test to full working pressure of the BOPE. All subsequent tests will be performed to
250 psi low / 3,850 psi for the BOPE and the annular will be tested to 250 psi low / 2,500 psi. If the 21
day pressure testing cycle is not granted then the initial pressure test will be performed to 250 psi low /
3,850 psi for the BOPE and the annular will be tested to 250 psi low / 2,500 psi.
8. Test casing to 2600 psi for 30min.
9. PU 12-1/4” bit and rotary steerable drilling assembly. Run MWD / LWD logging tools in drill string as
required for directional monitoring and formation data gathering.
10. Drill out cement and 20' new hole. Perform FIT to 11.5 ppg EMW minimum.
11. Directionally drill 12-1/4” hole to casing point at +/-12,353’ MD / 4,068’ TVD. Run MWD/LWD logging tools
(LMWD Program: GR/RES/DIR) in drill string as required for directional monitoring and formation data
gathering.
12. Circulate wellbore clean and pull out of the hole to surface.
13. Rig up and run new 9-5/8” 47# T95 H563 casing.
14. Rig up and pump cement as per program. Displace cement with mud, check floats upon bumping plug. Top of
cement to be +/-5,996’ MD / 3,221’ TVD which is 250’ TVD above the intermediate 1 casing shoe.
15. Test casing to 3850 psi for 30min.
16. Pick up 8-1/2” bit by 9-1/2” under reamer and rotary steerable assembly on 5-7/8” x 4-1/2” DP string. RIH,
clean out cement to top of float equipment and
17. Drill out cement and 20' of new hole. Perform FIT to 11.5 ppg EMW minimum.
18. Install Managed Pressure Drilling (MPD) bearing assembly and displace to 9.5 ppg.
19. Directionally drill 8-1/2” x 9-1/2” Intermediate 2 hole to casing point at +/-12,353’ MD / 4,068’ TVD, landing
~15’ TVD above top of Narwhal Central Sand. Run MWD/LWD logging tools (LMWD Program:
GR/RES/DEN/NEU/DIR) in drill string as required for directional monitoring and formation data gathering.
20. Circulate well clean, flow check and strip out of hole to surface.
21. Rig up and run new 7.625” 29.7# L80 H523 with 7.625” 39.0# P110S H523 Heavy Heel casing, hanger and
liner top packer on DP.
22. Rig up and pump cement as per program. Displace cement with mud, check floats upon bumping plug. Top of
cement to be +/-8,996’ MD / 3,632’ TVD which is 1500’ MD above top of uppermost possible hydrocarbon
bearing zone K3 to provide sufficient isolation and reduce losses during the cementing job due to weak
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
formations. Offset wells CD4-595, CD4-594, CD4-597, CD4-588, and CD4-586 have been approved by
AOGCC on same cement design.
23. Test casing to 3850 psi for 30min.
24. Pick up 6-1/2” Bit and rotary steerable drilling assembly and RIH and clean out cement to top of float
equipment.
25.Drill out cement and 20' of new hole. Perform FIT to a minimum of 10 ppg EMW. Displace to 8.6 ppg NAF
drilling fluid.
26. Directionally drill 6-1/2” hole into the Narwhal Lefty Sand to TD at +/- 20,712’ MD / 4,368’ TVD as per
directional plan. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/SON/DIR) in drill
string as required for directional monitoring and formation data gathering. Run Sonic log for 7.625” liner TOC
and report to AOGCC once it’s available.
27. Circulate well clean, flow check and backream out of hole to intermediate II shoe.
28. Displace to KW fluid and observe well for flow. Trip out of hole on elevators and lay down BHA.
29. PU and run 4-1/2” 12.6# P110S HYD563 lower completion, and line to TD.
30. PU and run 4-1/2” 12.6# L80 HYD563 tubing upper completion, circulate around with kill weight brine.
31. Land tubing.
32. Nipple down BOPE, nipple up tree and test against BPV.
33. Freeze protect 4-1/2” x 9-5/8” annulus with diesel.
34. Set BPV, secure well and move rig off.
14.Discussion of Mud and Cuttings Disposal and Annular Disposal
(Requirements of 20 AAC 25.005 (c)(14))
Drill cuttings and drilling mud form the well will be disposed of by hauling to Alpine injection facility where they
will be disposed by injecting to approved Class I or Class II Disposal wells.
15.Attachments
Attachment 1 Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Directional Plan
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
Attachment 1 – Cement Summary
13-3/8” Surface Casing to 2,645’ MD / 2,417’ TVD
Cement from 2,645’ to 2,145' MD (500’) with 15.8ppg Class G tail and from 2,145' to surface with 11.0ppg
DeepCRETE lead. Assume 200% excess annular volume in Permafrost, 50% excess below the Permafrost, and
no excess within the 20” conductor.
Lead Slurry from 2,145’ MD to Surface with 11.0ppg DeepCRETE
Conductor (135’ – 55’) X 1.0454 ft3/ft X 1.0 (0% excess) = 84 ft3
Permafrost to Conductor (1,269’ – 135’) X 0.4206 ft3/ft X 3.0 (200% excess) = 1,431 ft3
Top of Tail to Permafrost (2,145’ – 1,269’) X 0.4206 ft3/ft X 1.5 (50% excess) = 553 ft3
Total Volume = 84 + 1,431 + 553 = 2,068 ft3 => 1,078 sx of 11.0ppg DeepCRETE @ 1.92 ft3 /sk
Tail Slurry from 2,645’ MD to 2,145’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (2,645’ – 2,145) X 0.4206 ft3/ft X 1.50 (50% excess) = 315 ft3
Shoe Joints (90’) X 0.8406 ft3/ft X 1.00 (0% excess) = 76 ft3
Total Volume = 315 + 76 = 391 ft3 => 334 sx of 15.8ppg Class G + additives @ 1.17 ft3/sk
9-5/8” Intermediate 1 Casing to 7,861’ MD / 3,471’ TVD
Cement from 7,861’ to 250’ TVD above the liner shoe with 15.8ppg Class G assuming 30% excess annular
volume.
Cement from 7,861’ MD to 5,996’ MD with 15.8ppg Class G + additives
Shoe to Top of Cement (7,861’ – 5,996’) X 0.313 ft3/ft X 1.40 (40% excess) = 817 ft3
Shoe Joint (120’) X 0.4110 ft3/ft X 1.00 (0% excess) = 49 ft3
Total Volume = 817 + 49 = 866 ft3 => 747 sx of 15.8ppg Class G + additives @ 1.16 ft3/sk
7-5/8” Intermediate 2 Casing to 12,353’ MD / 4,068’ TVD
COP requests to use 1500’MD above K3 sand. Cement from 12,353’ to 11,853’ (500’ MD) with 15.8
Class G Tail and from 11,853’ to 8,996’ MD (1500’ above the K3 sand) with extended lead slurry.
Cement from 11,853’ MD to 8,996’ MD with 15.8 ppg Class G + additives
11,853’ MD to Top of Cement (11,853’ – 8,996’) X 0.3941 ft3/ft X 1.3 (30% excess) = 1464 ft3
Total Volume = 1464 ft3 => 747 sx of 15.8 ppg Class G + additives @ 1.96 ft3/sk
AOGCC Application for Permit to Drill, Well CD4-536
Saved: 31-Aug-23
CD4-536 AOGCC APD
Printed: 31-Aug-23
Tail Slurry from 12,353’ MD to 11,853’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (12,353’ – 11,853) X 0.3941 ft3/ft X 1.30 (30% excess) = 256 ft3
Shoe Joints (90’) X 0.2392 ft3/ft X 1.00 (0% excess) = 21 ft3
Total Volume = 256 + 21 = 277 ft3 => 239 sx of 15.8ppg Class G + additives @ 1.16 ft3/sk
Narwhal
Base Perm
16”
X
13 3/8"
68# L80 HYD563
12 1/4”
X
9 5/8"
47# T95 H563
8.2 ppg
VersaClean
w/ MPD
Notes
Pore Pressure/
Loss GradientMudHole/Casing
Size
Casing/Cement
MD’ / TVD’Geo TopsMD/TVD
CD4-536 Narwhal Horizontal Producer
Plan
0 inc 90
0 Azi 360
5 7 9 11 13 15
8.3
ppg
13.3
ppg
12.6
ppg
10.8 ppg FWP
C-30
C-40
Geosteer
9.0 ppg
86° inc
149° Azi
1269/1258
2,645/2,417
20,998/4,221
89° inc
150° Azi
48° inc
118° Azi
10.5 ppg
DRILPLEX AR
Trip Wt. 10.1 ppg
Narwhal Central
BHAs
16” Kymera Bit
+ Motor +
MWD+ LWD +
GWD
5-7/8"DP
12 1/4" PDC
RSS + MWD
+LWD (GR/
RES/PWD)
5-7/8"DP
FMC SBB
WellHead w/
4-½” tbg Hgr.
7,861/3,471
20" Conductor
@ 135'
C-10
4729/3027
12564/4083
10.6
ppg
Possible to see
Alpine forrest
down to 700'
MD
2675/2437
10496/3845
3304/2767
C-20
81.8° inc
116° Azi
Keep drilling
ECD below
12.8 ppg
Use MPD to
maintain static
balance. Keep
ECD below
10.6 ppg
8.4
ppg
2349/2207
K-3
6 1/2" PDC RSS
+ MWD +LWD
(GR/RES/NEU/
DEN/PWD/
SonicScope/
PeriScope/
GeoSphere/
PixStar)
5-7/8"x
4-1/2"DP
Use MPD to
hold CBHP at
bit for
wellbore
stability
G
L
G
L
D
S
X
G
L
G
L
12,353/4,068
TOL: 12,203/
4,057
TOC @ 8,996/
3,632
8 ½” x 9 ½” OH
6787/3319
Fault 40-60'
throw
12.8
ppg
7-5/8"
29.7# L80 H523
+39# P110S
HYD523 heel
6-1/2” Hole
4-1/2"
12.6# TN110S
HYD563
9.6 ppg
11.1
ppg
17220/4167
Fault
TOL: 7,775/
3,449
TOC @ 5,996/
3,221'
9.0 ppg FWP
8 1/2" x 9 1/2”
PDC RSS +
MWD +LWD
(GR/RES/PWD)
5-7/8"DP
9.1
2
PIKKA UNIT
CO
L
V
I
L
L
E
R
I
V
E
R
U
N
I
T
36
4
17
24
34
27
6
13
3
25
32
2120
16
31
30
19
18
28
22
15
1 5
29
33
CD4
T1
1
N
,
R
4
E
,
U
M
T1
1
N
,
R
5
E
,
U
M
T10N, R5E, UM
T11N, R5E, UM
C
D
1
-
4
9
C
D
4
-
2
1
4
CD4-96APB1
C
D
1
-
4
8
C
D
2
-
5
3
CD
2
-
7
7
C
D
2
-
2
7
C
D
4
-
2
1
1
C
D
1
-
4
8
A
C
D
4
-
3
2
0
P
B
1
CD4-302
C
D
4
-
2
9
1
P
B
1
C
D
4
-
2
0
9
C
D
4
-
2
9
2
C
D
4
-
2
9
1
C
D
4
-
2
9
0
C
D
4
-
3
2
0
C
D
4
-
4
9
9
CD
4
-
0
3
C
D
4
-
2
8
9
C
D
4
-
2
9
8
P
B
1
CD
4
-
5
9
4
P
H
1
C
D
4
-
3
0
1
A
C
D
4
-
2
9
8
C
D
4
-
3
0
1
C
D
4
-
5
9
5
P
H
C
D
4
-
3
0
1
B
C
D
4
-
5
9
7
C
D
4
-
5
9
5
C
D
4
-
5
8
8
C
D
4
-
5
9
4
ADL388902
ADL372097
ADL392981
ADL380077
ADL391587
ADL393167
ADL392975
ADL393166
ADL384209
ADL372096
ADL392961
ADL380075
ADL380081
ADL380044
ADL388903
ADL384211
ADL380082
ADL384210
ADL391590
ADL393168
ADL380079
k
8/7/2023
010.5
Miles
CD4-536
PTD Map
Open Interval
Well Trajectory
Existing Well
2 Pad
Narwhal PA
Unit Boundary
CPAI Lease
Industry Lease
C
D
4
-
5
3
6
53 599
599 899
899 1299
1299 1799
1799 2499
2499 2999
2999 3499
3499 3999
3999 11999
11999 20999
CD4-536 wp05 Plan Summary
0
4
Do
g
l
e
g
S
e
v
e
r
i
t
y
0 3500 7000 10500 14000 17500 21000
Measured Depth
13-3/8" Surface Casing 9-5/8" Intermediate Casing
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
1468
1516
1565
1613
CD4-12
1468
1516
1565
1613
1471
1519
1568
1616
Nanuq 5
1673
1720
1768
1815
1861
1907
CD4-208
1673
1720
1768
1814
1861
1906
1673
1720
1768
1815
1861
1907
1673
1720
1768
1814
1861
1906
1673
1720
1768
1815
1861
1907
1249
1294
1338
CD4-213
1249
1294
1338
1249
1294
1338
1249
1294
1338
1249
1294
1338
757
804
851
897
CD4-319 100150200250300350401451501
552603653704755806
CD4-539 wp08
5364114164214264314364413463513562611661710759809
CD4-533 wp01
5364114164214264314
364414463513563612662712761810860909
959
1008
1058
CD4-534 wp01
5364114164214264314364414464514564
61366371376381286291296110111061111111601210126013101360140914591508155816071657170717561806185519051954200420542103215322022252230123512400245025002549259926482698274727972846289529442993
CD4-535 wp01
5364114164214264314364415465515565615665715
764
814
863
912
961
CD4-537 wp02 (NE5B C)
0
2500
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
0 2750 5500 8250 11000 13750 16500
Vertical Section at 132.59°
13-3/8" Surface Casing
9-5/8" Intermediate Casing
15
30
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 425 850 1275 1700 2125 2550 2975
Measured Depth
DDI
7.449
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
53.30 2100.00 CD4-536 wp05 (CD4-536) SDI_URSA1_I4
2100.00 2640.00 CD4-536 wp05 (CD4-536)MWD OWSG
2100.00 2640.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
2640.00 3640.00 CD4-536 wp05 (CD4-536) MWD OWSG
2640.00 8000.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
8000.00 12350.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
12350.00 13350.00 CD4-536 wp05 (CD4-536) MWD OWSG
12350.00 20998.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
Ground / 18.30
CASING DETAILS
TVD MD Name
2417.30 2645.84 13-3/8" Surface Casing
4068.30 12353.24 9-5/8" Intermediate Casing
4221.30 20998.00 4-1/2" Production Liner
Mag Model & Date: BGGM2023 31-Dec-23
Magnetic North is 14.07° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.54° 57172.31nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 53.30 0.00 0.00 53.30 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 500.00 2.00 118.00 499.96 -1.64 3.08 1.00 118.00 3.38 Start Build 1.50
4 700.00 5.00 118.00 699.56 -7.37 13.86 1.50 0.00 15.19 Start Build 2.00
5 1220.68 15.41 118.00 1211.30 -50.63 95.21 2.00 0.00 104.36 Start 103.73 hold at 1220.68 MD
6 1324.41 15.41 118.00 1311.30 -63.57 119.56 0.00 0.00 131.04 Start Build 2.50
7 2645.84 48.45 118.00 2417.30 -387.16 728.14 2.50 0.00 798.08 Start 20.00 hold at 2645.84 MD
8 2665.84 48.45 118.00 2430.57 -394.19 741.36 0.00 0.00 812.57 Start DLS 3.00 TFO -3.04
9 3780.14 81.84 116.31 2892.32 -847.31 1629.22 3.00 -3.04 1772.87 Start 7424.86 hold at 3780.14 MD
1011205.00 81.84 116.31 3945.58 -4104.91 8217.64 0.00 0.00 8827.94 Start DLS 3.00 TFO 84.69
11 12296.95 86.00 149.00 4064.37 -4831.20 9004.16 3.00 84.69 9898.50 Start 300.00 hold at 12296.95 MD
1212596.95 86.00 149.00 4085.30 -5087.72 9158.30 0.00 0.00 10185.58 CD4-NE1A (C) T1 110822 Start 20.00 hold at 12596.95 MD
1312616.95 86.00 149.00 4086.70 -5104.82 9168.57 0.00 0.00 10204.72 Start DLS 1.00 TFO -29.33
1412636.09 86.17 148.91 4088.00 -5121.18 9178.42 1.00 -29.3310223.04 Start 141.19 hold at 12636.09 MD
1512777.28 86.17 148.91 4097.44 -5241.82 9251.18 0.00 0.00 10358.25 Start DLS 2.00 TFO -28.35
1612790.53 86.40 148.78 4098.30 -5253.13 9258.02 2.00 -28.3510370.94 CD4-NE1A (C) T2 110822 Start DLS 2.00 TFO -23.22
1712806.11 86.69 148.66 4099.24 -5266.42 9266.09 2.00 -23.2210385.87 Start 40.74 hold at 12806.11 MD
1812846.85 86.69 148.66 4101.59 -5301.16 9287.25 0.00 0.00 10424.96 Start DLS 2.75 TFO 28.61
1912948.86 89.15 150.00 4105.30 -5388.83 9339.25 2.75 28.6110522.58 CD4-NE1A (C) T3 110822 Start 2350.00 hold at 12948.86 MD
2015298.86 89.15 150.00 4140.16 -7423.77 10514.12 0.00 0.0012764.67 Start DLS 4.00 TFO -90.06
21 15942.93 89.21 124.23 4149.54 -7891.69 10948.68 4.00 -90.0613401.27 Start 463.21 hold at 15942.93 MD
2216406.14 89.21 124.23 4155.92 -8152.26 11331.59 0.00 0.0013859.51 Start DLS 4.00 TFO 90.21
2317325.19 89.24 161.00 4168.80 -8870.00 11880.00 4.00 90.2114748.99 Start DLS 4.00 TFO 90.07
2417845.70 89.26 181.82 4175.67 -9381.80 11957.30 4.00 90.0715152.26 Start 107.84 hold at 17845.70 MD
2517953.54 89.26 181.82 4177.05 -9489.58 11953.87 0.00 0.0015222.67 Start DLS 4.00 TFO -90.41
2618749.02 89.16 150.00 4188.28 -10251.18 12145.01 4.00 -90.4115878.80 Start 240.00 hold at 18749.02 MD
2718989.02 89.16 150.00 4191.80 -10459.00 12265.00 0.00 0.0016107.78 Start DLS 1.00 TFO -93.23
2818991.45 89.16 149.98 4191.84 -10461.10 12266.21 1.00 -93.2316110.10 Start 2006.55 hold at 18991.45 MD
29 20998.00 89.16 149.98 4221.30 -12198.21 13270.12 0.00 0.0018024.77 CD4-NE1A (C) T4 110822 TD at 20998.00
FORMATION TOP DETAILS
TVDPath Formation
1188.67 Base Perm
2134.12 C-40
2364.93 C-30
2694.25 C-20
2954.74 C-10
3773.44 K-3
3857.88 K-3_FS1
3903.79 K-3_FS2
3949.46 K-3_FS3
3983.81 K-4_FS4
4010.58 Narwhal
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by Accepted by Approved by
Plan 54+18.3 @ 72.30usft (D26)
-2
5
0
0
0
25
0
0
50
0
0
75
0
0
True Vertical Depth
0
2
5
0
0
5
0
0
0
7
5
0
0
1
0
0
0
0
1
2
5
0
0
1
5
0
0
0
1
7
5
0
0
Ve
r
t
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a
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S
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c
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i
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a
t
1
3
2
.
5
9
°
13
-
3
/
8
"
S
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C
a
s
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9-
5
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8
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4-
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L
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1
0
0
0
2
0
0
0
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
13000
14000
15000
16000
17000
18000
19000
20000
20998
0°
3
0
°
60°
82°
86°
89°
89°
89°
89°
CD4-536 wp05
Ba
s
e
P
e
r
m
C-
4
0
C-
3
0
C-
2
0
C-
1
0
K-
3
K-
3
_
F
S
1
K-
3
_
F
S
2
K-
3
_
F
S
3
K-
4
_
F
S
4
Na
r
w
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CD
4
-
5
3
6
w
p
0
5
15
:
3
8
,
J
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y
2
6
2
0
2
3
Se
c
t
i
o
n
V
i
e
w
-1
2
5
0
0
-1
0
0
0
0
-7
5
0
0
-5
0
0
0
-2
5
0
0
0
South(-)/North(+)
-2
5
0
0
0
2
5
0
0
5
0
0
0
7
5
0
0
1
0
0
0
0
1
2
5
0
0
1
5
0
0
0
We
s
t
(
-
)
/
E
a
s
t
(
+
)
CD
4
-
N
E
1
A
(
C
)
T
3
1
1
0
8
2
2
CD
4
-
N
E
1
A
(
C
)
T
4
1
1
0
8
2
2
CD
4
-
N
E
1
A
(
C
)
T
1
1
1
0
8
2
2
CD
4
-
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E
1
A
(
C
)
T
2
1
1
0
8
2
2
13
-
3
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8
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S
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P
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4
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5
3
6
w
p
0
5
Wh
i
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d
r
i
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l
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p
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w
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15
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4
5
,
J
u
l
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2
6
2
0
2
3
3O
D
Q
9
L
H
Z
NAD27 Latitude: 70° 17' 31.026" N
NAD27 Longitude: 150° 59' 21.326" W
-A.Dewhurst 11SEP23
0
35
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 500 1000 1500 2000 2500
Partial Measured Depth
CD4-12
CD4-12PB1
Nanuq
5
CD4-208
CD4-208A
CD4-208AL1
CD4-208APB1
CD4-208PB1
CD4-213
CD4-213A
CD4-213B
CD4-213BPB1
CD4-213BPB2
CD4-319
CD4-539 wp08
CD4-533
wp01
CD4-534
wp01
CD4-535
wp01
CD4-537 wp02 (NE5B C)
Equivalent Magnetic Distance
CD4-536 wp05 Ladder View
0
150
300
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 3500 7000 10500 14000 17500 21000
Measured Depth
CD4-03
CD4-05
CD4-12
CD4-12PB1
Nanuq
5
CD4-16
CD4-17
CD4-208
CD4-208A
CD4-208AL1
CD4-208APB1
CD4-208PB1
CD4-209
CD4-210
CD4-210A
CD4-210APB1
CD4-210B
CD4-211
CD4-211L1
CD4-211L1-01
CD4-213
CD4-213A
CD4-213B
CD4-213BPB1
CD4-213BPB2
CD4-214
CD4-214L1
CD4-215
CD4-215L1
CD4-23
CD4-23PB1
CD4-23PB2
CD4-24
CD4-24PB1
CD4-24PB2
CD4-25
CD4-25L1
CD4-25PB1
CD4-26
CD4-27
CD4-27PB1
CD4-27PB2
CD4-27PB3
CD4-318
CD4-318A
CD4-318PB1
CD4-319
CD4-320
CD4-320PB1
CD4-321
CD4-322
CD4-539
wp08
CD4-595
CD4-597
CD4-96
CD4-96A
CD4-96APB1
Nanuq
3
CD4-529
wp01
CD4-530
wp01
CD4-531
wp02
CD4-532
wp01
CD4-533
wp01
CD4-534
wp01
CD4-535
wp01
CD4-537 wp02 (NE5B C)
CD4-541
wp07 (NE4A C)
CD4-542
wp01
Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
53.30 2100.00 CD4-536 wp05 (CD4-536) SDI_URSA1_I4
2100.00 2640.00 CD4-536 wp05 (CD4-536) MWD OWSG
2100.00 2640.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
2640.00 3640.00 CD4-536 wp05 (CD4-536) MWD OWSG
2640.00 8000.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
8000.00 12350.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
12350.0013350.00 CD4-536 wp05 (CD4-536) MWD OWSG
12350.00 20998.00 CD4-536 wp05 (CD4-536) MWD+IFR2+SAG+MS
18:22, July 26 2023
CASING DETAILS
TVD MD Name
2417.30 2645.84 13-3/8" Surface Casing
4068.30 12353.24 9-5/8" Intermediate Casing
4221.30 20998.00 4-1/2" Production Liner
53 600
600 900
900 1300
1300 1800
1800 2500
2500 3000
3000 3500
3500 4000
4000 12000
12000 21000
CD4-536 wp05 TC View
30
30
60
60
90
90
120
120
150
150
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
1539
1586
1631
1676
1720
1764
1807
1848
CD4-03
976
1026
1075
1125
1175
1224
1273
1321
1370
1419
1468
1516
1565
1613
1661
1708
1756
1802
1849
1894
CD4-12
976
1026
1075
1125
1175
1224
1273
1321
1370
1419
1468
1516
1565
1613
1661
1708
1756
1802
1849
1894
979
1029
1078
1128
1178
1227
1275
1324
1373
1422
1471
1519
1568
1616
1664
1711
1758
1805
1851
1897
Nanuq 5
5366116166216266316366416465515564613662
710758
805
CD4-16
5366116166216266316366416466515565
6146637117608078549009449861027
CD4-17
1382
1431
1480
1529
1577
1625
1673
1720
1768
1815
1861
1907
1952
1997
2041
2085
2128
CD4-208
1382
1431
1480
1529
1577
1625
1673
1720
1768
1814
1861
1906
1952
1996
2041
2084
2128
1382
1431
1480
1529
1577
1625
1673
1720
1768
1815
1861
1907
1952
1997
2041
2085
2128
1382
1431
1480
1529
1577
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1336
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46651656661666671576581486291095710031047108911311171
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166216266316365414463512561609657705753800847893939
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CD4-24
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166216266316365414463512561609657705753800847893939
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CD4-25
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365413462510558606653CD4-265476126176226276326374422
CD4-27
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5467117167217267317365414462
5476126176226276326374422
5367117167217267317367417466515564613661709756803849894
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5366116166216266316366416465514563612660708755802848893
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5367117167217267317367417466515564613661709756803849894
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5367117167217267317366416465515564
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5366116166216266315365414463512561
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CD4-320
5366116166216266315365414463512561
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5366116166216266316366415464513562610
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167217267
316366415464513
561609657705752798843
CD4-322
100150200250300350401451501
5526036537047558068569079581009106011111162121312641313136514161468152015721624167617291781183318861938
1991204420962149220222552308236124142467252025742627
CD4-539 wp08
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CD4-96
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5364114164214264314
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CD4-529 wp01
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CD4-530 wp01
5364114164214264314363413462511561610659707756805853
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CD4-541 wp07 (NE4A C)
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CD4-542 wp01
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
From To Tool
53.30 2100.00 SDI_URSA1_I4
2100.00 2640.00 MWD OWSG
2100.00 2640.00 MWD+IFR2+SAG+MS
2640.00 3640.00 MWD OWSG
2640.00 8000.00 MWD+IFR2+SAG+MS
8000.00 12350.00 MWD+IFR2+SAG+MS
12350.00 13350.00 MWD OWSG
12350.00 20998.00 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2417.30 2645.84 13-3/8" Surface Casing
4068.30 12353.24 9-5/8" Intermediate Casing
4221.30 20998.00 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 53.30 0.00 0.00 53.30 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 500.00 2.00 118.00 499.96 -1.64 3.08 1.00 118.00 3.38 Start Build 1.50
4 700.00 5.00 118.00 699.56 -7.37 13.86 1.50 0.00 15.19 Start Build 2.00
5 1220.68 15.41 118.00 1211.30 -50.63 95.21 2.00 0.00 104.36 Start 103.73 hold at 1220.68 MD
6 1324.41 15.41 118.00 1311.30 -63.57 119.56 0.00 0.00 131.04 Start Build 2.50
7 2645.84 48.45 118.00 2417.30 -387.16 728.14 2.50 0.00 798.08 Start 20.00 hold at 2645.84 MD
8 2665.84 48.45 118.00 2430.57 -394.19 741.36 0.00 0.00 812.57 Start DLS 3.00 TFO -3.04
9 3780.14 81.84 116.31 2892.32 -847.31 1629.22 3.00 -3.04 1772.87 Start 7424.86 hold at 3780.14 MD
1011205.00 81.84 116.31 3945.58 -4104.91 8217.64 0.00 0.00 8827.94 Start DLS 3.00 TFO 84.69
11 12296.95 86.00 149.00 4064.37 -4831.20 9004.16 3.00 84.69 9898.50 Start 300.00 hold at 12296.95 MD
1212596.95 86.00 149.00 4085.30 -5087.72 9158.30 0.00 0.0010185.58 CD4-NE1A (C) T1 110822 Start 20.00 hold at 12596.95 MD
1312616.95 86.00 149.00 4086.70 -5104.82 9168.57 0.00 0.0010204.72 Start DLS 1.00 TFO -29.33
1412636.09 86.17 148.91 4088.00 -5121.18 9178.42 1.00 -29.3310223.04 Start 141.19 hold at 12636.09 MD
1512777.28 86.17 148.91 4097.44 -5241.82 9251.18 0.00 0.0010358.25 Start DLS 2.00 TFO -28.35
1612790.53 86.40 148.78 4098.30 -5253.13 9258.02 2.00 -28.3510370.94 CD4-NE1A (C) T2 110822 Start DLS 2.00 TFO -23.22
1712806.11 86.69 148.66 4099.24 -5266.42 9266.09 2.00 -23.2210385.87 Start 40.74 hold at 12806.11 MD
1812846.85 86.69 148.66 4101.59 -5301.16 9287.25 0.00 0.0010424.96 Start DLS 2.75 TFO 28.61
1912948.86 89.15 150.00 4105.30 -5388.83 9339.25 2.75 28.6110522.58 CD4-NE1A (C) T3 110822 Start 2350.00 hold at 12948.86 MD
2015298.86 89.15 150.00 4140.16 -7423.77 10514.12 0.00 0.0012764.67 Start DLS 4.00 TFO -90.06
21 15942.93 89.21 124.23 4149.54 -7891.69 10948.68 4.00 -90.0613401.27 Start 463.21 hold at 15942.93 MD
2216406.14 89.21 124.23 4155.92 -8152.26 11331.59 0.00 0.0013859.51 Start DLS 4.00 TFO 90.21
2317325.19 89.24 161.00 4168.80 -8870.00 11880.00 4.00 90.2114748.99 Start DLS 4.00 TFO 90.07
2417845.70 89.26 181.82 4175.67 -9381.80 11957.30 4.00 90.0715152.26 Start 107.84 hold at 17845.70 MD
2517953.54 89.26 181.82 4177.05 -9489.58 11953.87 0.00 0.0015222.67 Start DLS 4.00 TFO -90.41
2618749.02 89.16 150.00 4188.28 -10251.18 12145.01 4.00 -90.4115878.80 Start 240.00 hold at 18749.02 MD
2718989.02 89.16 150.00 4191.80 -10459.00 12265.00 0.00 0.0016107.78 Start DLS 1.00 TFO -93.23
2818991.45 89.16 149.98 4191.84 -10461.10 12266.21 1.00 -93.2316110.10 Start 2006.55 hold at 18991.45 MD
29 20998.00 89.16 149.98 4221.30 -12198.21 13270.12 0.00 0.0018024.77 CD4-NE1A (C) T4 110822 TD at 20998.00
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20
9
9
8
.
0
0
1
4
9
.
9
8
0
.
0
0
CD
4
-
5
3
6
w
p
0
5
Sp
i
d
e
r
P
l
o
t
17
:
0
0
,
J
u
l
y
2
6
2
0
2
3
54
.
0
0
T
o
2
0
9
9
8
.
1
8
Northing (4500 usft/in)
Ea
s
t
i
n
g
(
4
5
0
0
u
s
f
t
/
i
n
)
38131
8
23 28 33 38 43 4
8
CD4-03
381 31823
2 8
3 3
3 8
4 3
4 8
CD4-05
3813
18
23
28
33
38
43
48
CD4-07
3
81
3
1
8 2
3 28
33
3 8
4 3
4 8
CD4-12
3
81
3
1
8 2
3 28
33
3 8
4 3
4 8
CD4-12PB1
3
81
3
1
8 2
3 2
8 3
3 3
8 4
3 4
8
Nanuq 5
3813
18
2 3
2 833
3 8
4 3
48
CD4-16
381 318
23
2 8
3 3
3 8
4 3
4 8
CD4-17
381
3
1
8
2
32
8
3
33
8
43
48
CD4-208
381
3
1
8
2
32833
38
43
48
CD4-208A
381
3
1
8
2
32833
38
43
48
CD4-208AL1381
3
1
8
2
32833
38
43
48 CD4-208APB1
381
3
1
8
2
32
8
3
33
8
43
48
CD4-208PB1
3
8 1318232833384348
CD4-209
381 318232833384348
CD4-210
381 318232833 38
43
48
CD4-210A
381 318232833 38
43
48 CD4-210APB1
381 318232833 38
43
48
CD4-210B
3813
1 823283338
4 348
CD4-211
3813
1 823283338
4 348
CD4-211L1
3813
1 823283338
4 348
CD4-211L1-01
381318
23283338
4348
CD4-213
381318
232833
3 84348CD4-213A
381318
23
2 8
3 3
3 8
4 3
4 8
CD4-213B
381318
23
2 8
3 3
3 8
4 3
4 8
CD4-213BPB1
381318
23
2 8
3 3
3 8
4 3
4 8
CD4-213BPB2
3 81 31 82 32 83 33 84 34 8
CD4-214
3 81 31 82 32 83 33 84 34 8
CD4-214L1
381 31 8
2 3
2 8
3 3
3 84 3 4 8
CD4-215381318
2 3
2 8
3 3
3 84 3 4 8
CD4-215L1
3813
1 8
2 3
2 8
3 33 8
4 3
4 8 CD4-23
3813
1 8
2 3
2 8
3 33 8
4 3
4 8
CD4-23PB1
3813
1 8
2 3
2 8
3 33 8
4 3
4 8
CD4-23PB2
3 81318
23
28
33
38
43
48
CD4-24
3 81318
23
28
33
38
43
48
CD4-24PB1
3 81318
23
28
33
38
43
48
CD4-24PB2
381318
23
28
33
38
43
48
CD4-25
381318
23
28
33
38
43
48
CD4-25L1
381318
23
28
33
38
43
48
CD4-25PB1
3
8 1 31 8
2 3
2 8
3 3
3 8
4 3
4 8
CD4-26
381318
23
28
33
38
43
48
CD4-27
381318
23
28
33
38
43
48
CD4-27PB1
381318
23
28
33
38
43
48
CD4-27PB2
381318
23
28
33
38
43
48
CD4-27PB3
3 81 318
232833384348
CD4-289
3 81318232833384348
CD4-290
3
81318232833384348
CD4-291
3
81318232833384348
CD4-291PB1
3
8
1
3
1
8
2
3
2
8
3
3
3
8
4
3
4
8
CD4-292
3
8
1 3
18 23
28 33
38
43 48
CD4-298
3
8
1 3
18 23
28 33
38
43 48
CD4-298PB1
381318
23
28
33
38
43
48
CD4-301
381318
23
28
33
38
43
48
CD4-301A
381318
23
28
33
38
43
48
CD4-301B
381318
23
28
33
38
43
48
CD4-302
3
81
3
18
23
28
33
38
43
48
CD4-304
3
81
3
18
23
28
33
38
43
48
CD4-304PB1
381
3
18
23
28
33
38
43
48
CD4-306
3
81 31 8
2 3
2 8
3 3
3 8
4 3
4 8
CD4-318
3
81 31 8
2 3
28
3 3
3 8
4 3
4 8
CD4-318A
3
81 31 8
2 3
2 8
3 3
3 8
4 3
4 8
CD4-318PB1
3813
18
23
28
33
38
43
48
CD4-319
381318232833384348
CD4-320
381318232833384348
CD4-320PB1
381318
2 3
2 8
3 3
3 8
4 3
4 8
CD4-321
3
813
18
23
28
33
38
43
48
CD4-322
3813
1 8
2328
33
3
8
CD4-499
38131823
28
33
38
CD4-539 wp08
3
81 31823
28
33
CD4-586
3
81 31823
28
33
38
4
3
CD4-586 wp07.1
381 31823
2 8
3 3
38
4
3
CD4-588
381318
23
28
33
38
4
3
CD4-594
381318
23
28
33
38
43CD4-594PH1
381
31
8
2
3
28
33
38
4
3
CD4-595
381
31
8
2
3
28
33
3
8
4
3
4
8
CD4-595PH1
381
31
82
3
28
3
3
3
8
4
3
CD4-597
381
3
18
23
28
33
38
43
48
CD4-93
381
3
18
23
28
33
38
43
48
CD4-93A
3
8 1318
23
2 8
3 3
3 8
4 3
4 8
CD4-96
3
8 1318
23
2 8
3 3
3 8
4 3
4 8
CD4-96A
3
8 1318
23
2 8
3 3
3 8
4 3
4 8
CD4-96APB1
3813
1 823
2833384348
Nanuq 3
38131823 28 3
3 3
8
CD4-529 wp01
381
3
1
82
3 2
8
3
3
3
8
CD4-530 wp01
38
1
3
1
82
3
2
8
3
3
3
8
CD4-531 wp02
38
1
3
1
82
3
2
8
3
3
3
8
CD4-532 wp01
381
31
82
3
2
8
3
3
3
8
CD4-533 wp01
381
31
82
3
2
8
3
3
3
8
CD4-534 wp01
38131823
28
33
38
CD4-535 wp01
381 3182328
3 3
3 8
CD4-537 wp02 (NE5B C)
381318
23
2 8
3 3
38
CD4-541 wp07 (NE4A C)
3
81 31823
2 8
3 3
3 8
CD4-542 wp01
381318
23
28
33
38
CD4-587 wp07 (NE3A C)
38131823
28
33
38
CD4-536 wp05
CD
4
-
5
3
6
w
p
0
5
Sp
i
d
e
r
P
l
o
t
17
:
0
2
,
J
u
l
y
2
6
2
0
2
3
54
.
0
0
T
o
2
0
9
9
8
.
1
8
Northing (1500 usft/in)
Ea
s
t
i
n
g
(
1
5
0
0
u
s
f
t
/
i
n
)
3813 1
8 23 28
33 38 4
3 4
8 CD4-03
381 3
1 8
2 3CD4-05
38
13
18
CD4-07
3
81
3 1
8
2
3 28
33
3 8
4 3CD4-12
3
81
3 1
8
2
3 28
33
3 8
4 3CD4-12PB13
81
3 1
8
2
3
2
8
3
3
3
8
4
3
4
8
Nanuq 5
38
13
CD4-16
38
1 3CD4-17
38 1
3 1
8 23 2
8 3
3 3
8 4
3
48
CD4-208
38 1
3 1
8 23 28
33
38
43
48
CD4-208A
38 1
3 1
8 23 28
33
38
43
48
CD4-208AL1
38 1
3 1
8 23 28
33
38
43
48
CD4-208APB1
38 1
3 1
8 23 2
8 3
3 3
8 4
3
48
CD4-208PB1 3
8 13182328333843
48
CD4-209
38 1 3
18
23
28CD4-210
38 1 3
18
23
28
CD4-210A
38 1 3
18
23
28CD4-210APB1
38 1 3
18
23
28
CD4-210B
3813
1 8
2 3
CD4-211
3813
1 8
2 3CD4-211L1
3813
1 8
2 3CD4-211L1-01
3 8 13
18
23
CD4-213
3 8 13
18
23
28 33
CD4-213A
3 8 13
18
23
CD4-213B
3 8 13
18
23
CD4-213BPB1
3 8 13
18
23
CD4-213BPB2
3 8 1 3
1 8
CD4-2143813
1 8CD4-214L138 1 3
1 8CD4-215 38 1 3
1 8CD4-215L1 3813
1 8
CD4-23
3813
1 8
CD4-23PB13813
1 8
CD4-23PB23813
18
CD4-24
3 8 13
18
CD4-24PB13813
18
CD4-24PB23813
18
CD4-253813
18
CD4-25L13813
18
CD4-25PB13
8 1 3
1 8CD4-26 38 13
CD4-2738 13
CD4-27PB1
38 13
CD4-27PB2
38 13
CD4-27PB3
3 81 318
23
28
33
38
43
48
CD4-289
3 81318
23
28
33
38
43
48
CD4-290
381318
23
2833
38
4348
CD4-291
381318
23
2833
38
4348
CD4-291PB1
3
8
1
3
1
8
2
3
2
8
3
3
3
8
4
3
4
8
CD4-292
3
8 1 3
18
23
28
3 3
38
43
48
CD4-298
3
8 1 3
18
23
28
3 3
38
43
48
CD4-298PB1
38
13
18
23
28
33
38
43
48
CD4-301
38
13
18
23
28
33
38
43
48
CD4-301A
38
13
18
23
28
33
38
43
48
CD4-301B
38
13
18
23
28
33
38
43
48
CD4-302
3
81
3
18
23
CD4-304
3
81
3
18
23
CD4-304PB1
38
1
3
18
23
CD4-306
3
8 1 3
CD4-318
3
8 1 3
CD4-318A
3
8 1 3
CD4-318PB1 38 13
18
CD4-319
381318232833
CD4-320
381318232833
CD4-320PB1
38
13CD4-321 3
8
13
CD4-322
3813
1 8
23
28
33
3
8
CD4-499
38
13
18
23
28
33
38
CD4-539 wp08
3 81 3
1 8
2 3
28
33
CD4-586
3
81 3
1 8
2 3
28
33
38
CD4-586 wp07.1
3813
1 8
2 3
28
3 3
38
CD4-588
38
13
18
23
28
33
38
CD4-594
38
13
18
23
28
33
38
43
CD4-594PH1
38
1
3
1
8
2
3
28
33
38
CD4-595
38
1
3
1
8
2
3
28
33
CD4-595PH1
38
1
3
1
8
2
3
2
8
3
3
3
8
CD4-597
381
3
18
23
CD4-93
381
3
18
23
CD4-93A
3
8
13
18
23
CD4-96
3
8
13
18
23
CD4-96A
3
8
13
18
23
CD4-96APB1
38
13Nanuq 3
3813
18
23
28
3
3
3
8
CD4-529 wp01
381
3 1
8
2
3
2
8
3
3
3
8
CD4-530 wp01
38
1
3
1
8
2
3
2
8
3
3
3
8
CD4-531 wp02
38
1
3
1
8
2
3
2
8
3
3
3
8
CD4-532 wp01
38
1
3
1
8
2
3
2
8
3
3
3
8
CD4-533 wp01
38
1
3
1
8
2
3
2
8
3
3
3
8
CD4-534 wp01
3813
18
23
28
33
38
CD4-535 wp01
381318
2 3
28
3 3
CD4-537 wp02 (NE5B C)
38
13
18
23
2 8
3 3
38
CD4-541 wp07 (NE4A C)
381 318
2 3
2 8
CD4-542 wp01
3813
18
23
28
33
38
CD4-587 wp07 (NE3A C)
3813
18
23
28
33
38
CD4-536 wp05
CD
4
-
5
3
6
w
p
0
5
Sp
i
d
e
r
P
l
o
t
17
:
0
5
,
J
u
l
y
2
6
2
0
2
3
54
.
0
0
T
o
2
0
9
9
8
.
1
8
Northing (200 usft/in)
Ea
s
t
i
n
g
(
2
0
0
u
s
f
t
/
i
n
)
2468 10
12 14 16 1
8 20
CD4-03
24
6
8
1 0
1 2
14
1 6
1 8
2 0
CD4-05
24
6
8
1
0
1
2
14
16
CD4-07
24
6 8
1
0 1
2
1
4
1
6
1
8
2
0
2
2 CD4-12
24
6 8
1
0 1
2
1
4
1
6
1
8
2
0
2
2 CD4-12PB1
24
6 8
1
0 1
2
1
4
1
6
1
8
2
0
2
2 Nanuq 5
24
6
8
10
12
CD4-16
24
6
8
1 0
1 2
CD4-17
246
8
1
0 1
2 1
4 1
6 1
8 2
0 22 2
4 2
6 2
8 3
0
CD4-208
246
8
1
0 1
2 1
4 1
6 1
8 2
0 22 2
4 26
28
30
CD4-208A
246
8
1
0 1
2 1
4 1
6 1
8 2
0 22 2
4 26
28
30
CD4-208AL1
246
8
1
0 1
2 1
4 1
6 1
8 2
0 22 2
4 26
28
30
CD4-208APB1
246
8
1
0 1
2 1
4 1
6 1
8 2
0 22 2
4 2
6 2
8 3
0
CD4-208PB1
24681012
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
CD4-209
2468 10
1 2
14
16
18
20
22CD4-210
2468 10
1 2
14
16
18
20
22CD4-210A
2468 10
1 2
14
16
18
20
22CD4-210APB1
2468 10
1 2
14
16
18
20
22CD4-210B
24681
0
12
14
1 6
1 8
CD4-211
24681
0
12
14
1 6
1 8
CD4-211L1
24681
0
12
14
1 6
1 8
CD4-211L1-01
2468 10
12
14
16
18
20
CD4-213
2468 10
12
14
16
18
20
CD4-213A
2468 10
12
14
16
18
20
CD4-213B
2468 10
12
14
16
18
20
CD4-213BPB1
2468 10
12
14
16
18
20
CD4-213BPB2
2
4 6 8
1 0
1 2
1 4
1 6CD4-214
2
4 6 8
1 0
1 2
1 4
1 6CD4-214L1
246
8
1 0
1 2
1 4
CD4-215
246
8
1 0
1 2
1 4
CD4-215L1
246 8 10
12
14
16
CD4-23
246 8 10
12
14
16
CD4-23PB1
246 8 10
12
14
16
CD4-23PB2
2 46 8 10
12
14
CD4-24
2 46 8 10
12
14
CD4-24PB1
2 46 8 10
12
14
CD4-24PB2
246 8
10
12
CD4-25
246 8
10
12
CD4-25L1
246 8
10
12
CD4-25PB1
2
4 6 8
1 0CD4-26 2 4 6CD4-272 4 6CD4-27PB124 6CD4-27PB224 6CD4-27PB3
2
4681012
1 4
16
18
20
22
24
26
28
CD4-289
24
68
1
0
1
2
14
16
18
20
22
24
26
28
30
32
CD4-290
246810
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
CD4-291
246810
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
CD4-291PB1
24 68
10 1
21
4 1
6 1
8 2
0 2
2 2
4 2
6 2
8 3
0 3
2 3
4 3
6 3
8 4
0 4
2 4
4 4
6 4
8 5
0
5
2
5
4
5
6
5
8 CD4-292
246
8
10
12
1 4
16
18
20
22
CD4-298
246
8
10
12
1 4
16
18
20
22
CD4-298PB1
24
6
8
10
12
14
16
18
20
22
CD4-301
24
6
8
10
12
14
16
18
20
22
CD4-301A
24
6
8
10
12
14
16
18
20
22
CD4-301B
246
8
10
12
14
16
18
20
22
24
26
CD4-302
24
6
8
1
0
1
2
14
16
CD4-304
24
6
8
1
0
1
2
14
16
CD4-304PB1
2
4
68
1
0
1
2
1
4
CD4-306
24
6
8
1 0
1 2
CD4-318
24
6
8
1 0
1 2
CD4-318A
24
6
8
1 0
1 2
CD4-318PB1
24 6 8
10
12
14
CD4-319
24
6
8
1
01214
CD4-320
24
6
8
1
01214CD4-320PB1
246
8
1 0
CD4-321
2
468
10
CD4-322
24681012141618
20
22
24
26
28
30
32
34
36
3
8
CD4-499
0246
8
10
12
14
16
18
20
22
24
26
CD4-539 wp08
2468
1 0
1 2
1 4
1 6
1 8
2 0
2 2
CD4-586
02
468
1 0
1 2
1 4
1 6
1 8
2 0
2 2
CD4-586 wp07.1
2 468
1 0
1 2
1 4
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CD4-588
2
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10
12
14
16
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20
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CD4-594
2
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CD4-595
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CD4-96
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CD4-208PB1
18
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1 2
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CD4-210
1 2
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CD4-210A
1 2
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16
18
CD4-210APB1
1 2
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16
18
CD4-210B
10
12
14
CD4-213
10
12
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CD4-213A
10
12
14
CD4-213B
10
12
14
CD4-213BPB1
10
12
14
CD4-213BPB2
1 0
1 2
CD4-214
1 0
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CD4-214L1
1 0
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CD4-215
1 0
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CD4-215L1
24 6 8
CD4-23
24 6 8
CD4-23PB1
24 6 8
CD4-23PB2
2 4
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CD4-319
2CD4-320
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CD4-539 wp08
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24
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24
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24
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24
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24
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24
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CD4-536wp05 Surface Location
CD4-536wp05 Surface Location
CD4-536wp05 Surface Casing
CD4-536wp05 Surface Casing
CD4-536wp05 Intermediate Casing 1
CD4-536wp05 Intermediate Casing 1
CD4-536wp05 Top Narwhal Central
CD4-536wp05 Top Narwhal Central
CD4-536wp05 TD
CD4-536wp05 TD
CD4
PHONE : 907-670-4739
PHONE : 907-670-4739
PHONE : 907-670-4739
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-A.Dewhurst 12SEP23
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Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Tuesday, September 12, 2023 12:56
To:Hobbs, Greg S
Cc:Davies, Stephen F (OGC); Cremer, Justin; Guhl, Meredith D (OGC)
Subject:RE: [EXTERNAL]CRU CD4 536 (PTD 223-079)
Greg,
You are correct that we won’t need signed “as-built” plats for each well on the same pad going forward. But it looks like
the CD4 pad was recently expanded. From what I can tell, the 539 and 536 wells are in a new row. I didn’t notice that for
the 539, so we just need the new survey this one time.
What I suggest is that unless the pad changes again in the future, or for any other reason gets re-surveyed, that you
insert a phrase into future CD4 PTDs that the certified plat is on record at the AOGCC under PTD 223-079. Then you
won’t need to include any other info.
Andy
From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent: Monday, September 11, 2023 15:17
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Cremer, Justin <Justin.Cremer@conocophillips.com>
Subject: RE: [EXTERNAL]CRU CD4 536 (PTD 223-079)
Hi Andy,
I called Chris Zeimet at our survey office in Alpine. The office has typically applied the certificate to our documents for
filing internally, but it is not signed. Lounsbury does not have a certificate on their plats or a signature. All plats are filed
internally for use in permits or projects.
I will direct the Alpine Survey office to leave the certificate off future documents as they require separate signature for
each document which we reached out for and received this morning for this document. It is attached. All plats have the
initials of the surveyor and a reviewer for accuracy.
Let me know if there are further questions or concerns-
Thanks!
Greg
From: Cremer, Justin <Justin.Cremer@conocophillips.com >
Sent: Monday, September 11, 2023 1:01 PM
To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: Fwd: [EXTERNAL]CRU CD4 536 (PTD 223-079)
Greg,
2
Have you made any headway on the signature?
Justin
Get Outlook for iOS
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Monday, September 11, 2023 12:50:36 PM
To: Cremer, Justin <Justin.Cremer@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp,
Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: [EXTERNAL]CRU CD4 536 (PTD 223-079)
Justin,
Sorry for the delayed response. I was out of the office for a few days last week.
x I received the plat and updated schematic. Looks good.
x The signature requested is for the “as-built” survey shown below:
Nothing additional is needed for the directional plan.
Andy
From: Cremer, Justin <Justin.Cremer@conocophillips.com >
Sent: Thursday, September 7, 2023 08:51
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp,
Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: Re: [EXTERNAL]CRU CD4 536 (PTD 223-079)
3
Good Morning Andy,
I apologize for leaving off the plat. Please find it attached. I do not have the survey signed at this point as there is
potential for a slight plan shift in the heal once we see the reservoir results from CD4=539. Is a signed survey a
requirement for the permit? I am in the process of getting this one signed now and will forward once it is
completed.
The coordinates are below for the surface location:
I have updated the schematic to match the pore pressure expected as detailed in section 4. The Narwhal
formation has been affected through previous production in the CD4-536 location and as such is expected to be
lower from the previous permits we have submitted.
Thank you,
Justin Cremer
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Wednesday, September 6, 2023 3:20 PM
To: Cremer, Justin <Justin.Cremer@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp,
Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: [EXTERNAL]CRU CD4 536 (PTD 223-079)
You don't often get email from justin.cremer@conocophillips.com. Learn why this is important
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
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4
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Justin,
I’m completing the review of the CD4-536 and had a couple of questions:
x Would you please send a PDF of the well plat with lease boundaries?
x Do you have a copy of survey that has been signed?
x I didn’t see any coordinates on the directional plan; I see the NAD 27 State Plane coordinates on the 10-401
form, but would you send me the NAD 27 lat/long coordinates also?
x It looks like you are expecting pore pressure of 9.6 ppg EMW in the reservoir (as depicted on well diagram and
as per previous PTDs) . However, the expected pore pressures from Section 4 don’t show much higher than ~9.1.
Would you confirm the expected pore pressures for the Narwhal sand?
For everything above besides the plat and survey, it’s easiest if I just append the current PTD application with the
updated values; no need to re-draft figures or text.
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
223-079
NARWHAL UNDEFINED OIL
CRU CD4-536
COLVILLE RIVER
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I
L
L
E
R
I
V
E
R
,
Q
A
N
N
I
K
O
I
L
-
1
2
0
1
8
0
NA
1
Pe
r
m
i
t
f
e
e
a
t
t
a
c
h
e
d
Ye
s
AD
L
3
8
0
0
7
7
,
A
D
L
3
8
4
2
1
1
,
A
D
L
3
8
8
9
0
3
,
A
D
L
3
9
1
5
8
7
,
A
D
L
3
8
0
0
8
2
2
Le
a
s
e
n
u
m
b
e
r
a
p
p
r
o
p
r
i
a
t
e
Ye
s
3
Un
i
q
u
e
w
e
l
l
n
a
m
e
a
n
d
n
u
m
b
e
r
Ye
s
CO
L
V
I
L
L
E
R
I
V
E
R
,
Q
A
N
N
I
K
O
I
L
-
1
2
0
1
8
0
4
W
e
l
l
l
o
c
a
t
e
d
i
n
a
d
e
f
i
n
e
d
p
o
o
l
Ye
s
5
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
d
r
i
l
l
i
n
g
u
n
i
t
b
o
u
n
d
a
r
y
NA
6
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
o
t
h
e
r
w
e
l
l
s
Ye
s
7
Su
f
f
i
c
i
e
n
t
a
c
r
e
a
g
e
a
v
a
i
l
a
b
l
e
i
n
d
r
i
l
l
i
n
g
u
n
i
t
Ye
s
8
If
d
e
v
i
a
t
e
d
,
i
s
w
e
l
l
b
o
r
e
p
l
a
t
i
n
c
l
u
d
e
d
Ye
s
9
Op
e
r
a
t
o
r
o
n
l
y
a
f
f
e
c
t
e
d
p
a
r
t
y
Ye
s
10
Op
e
r
a
t
o
r
h
a
s
a
p
p
r
o
p
r
i
a
t
e
b
o
n
d
i
n
f
o
r
c
e
Ye
s
11
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
c
o
n
s
e
r
v
a
t
i
o
n
o
r
d
e
r
Ye
s
12
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
a
d
m
i
n
i
s
t
r
a
t
i
v
e
a
p
p
r
o
v
a
l
Ye
s
13
Ca
n
p
e
r
m
i
t
b
e
a
p
p
r
o
v
e
d
b
e
f
o
r
e
1
5
-
d
a
y
w
a
i
t
NA
14
W
e
l
l
l
o
c
a
t
e
d
w
i
t
h
i
n
a
r
e
a
a
n
d
s
t
r
a
t
a
a
u
t
h
o
r
i
z
e
d
b
y
I
n
j
e
c
t
i
o
n
O
r
d
e
r
#
(
p
u
t
I
O
#
i
n
c
o
m
m
e
n
t
s
)
(
F
o
r
s
e
r
v
NA
15
Al
l
w
e
l
l
s
w
i
t
h
i
n
1
/
4
m
i
l
e
a
r
e
a
o
f
r
e
v
i
e
w
i
d
e
n
t
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
16
Pr
e
-
p
r
o
d
u
c
e
d
i
n
j
e
c
t
o
r
:
d
u
r
a
t
i
o
n
o
f
p
r
e
-
p
r
o
d
u
c
t
i
o
n
l
e
s
s
t
h
a
n
3
m
o
n
t
h
s
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
17
No
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
t
o
A
S
3
1
.
0
5
.
0
3
0
(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
D
)
Ye
s
18
Co
n
d
u
c
t
o
r
s
t
r
i
n
g
p
r
o
v
i
d
e
d
Ye
s
Su
r
f
a
c
e
c
a
s
i
n
g
s
e
t
t
o
2
6
4
5
'
M
D
19
Su
r
f
a
c
e
c
a
s
i
n
g
p
r
o
t
e
c
t
s
a
l
l
k
n
o
w
n
U
S
D
W
s
Ye
s
12
1
%
e
x
c
e
s
s
p
l
a
n
n
e
d
20
CM
T
v
o
l
a
d
e
q
u
a
t
e
t
o
c
i
r
c
u
l
a
t
e
o
n
c
o
n
d
u
c
t
o
r
&
s
u
r
f
c
s
g
No
21
CM
T
v
o
l
a
d
e
q
u
a
t
e
t
o
t
i
e
-
i
n
l
o
n
g
s
t
r
i
n
g
t
o
s
u
r
f
c
s
g
No
Pr
o
d
u
c
t
i
v
e
i
n
t
e
r
v
a
l
w
i
l
l
b
e
c
o
m
p
l
e
t
e
d
w
i
t
h
u
n
c
e
m
e
n
t
e
d
l
i
n
e
r
w
i
t
h
f
r
a
c
s
l
e
e
v
e
s
22
CM
T
w
i
l
l
c
o
v
e
r
a
l
l
k
n
o
w
n
p
r
o
d
u
c
t
i
v
e
h
o
r
i
z
o
n
s
Ye
s
23
Ca
s
i
n
g
d
e
s
i
g
n
s
a
d
e
q
u
a
t
e
f
o
r
C
,
T
,
B
&
p
e
r
m
a
f
r
o
s
t
Ye
s
Ri
g
h
a
s
s
t
e
e
l
t
a
n
k
s
;
a
l
l
w
a
s
t
e
t
o
a
p
p
r
o
v
e
d
d
i
s
p
o
s
a
l
w
e
l
l
s
24
Ad
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
NA
25
If
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
An
t
i
-
c
o
l
l
i
s
i
o
n
a
n
a
l
y
s
i
s
c
o
m
p
l
e
t
e
;
n
o
m
a
j
o
r
r
i
s
k
f
a
i
l
u
r
e
s
26
Ad
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
Di
v
e
r
t
e
r
v
a
r
i
a
n
c
e
g
r
a
n
t
e
d
p
e
r
2
0
A
A
C
2
5
.
0
3
5
(
h
)
(
2
)
27
If
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
Ma
x
r
e
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
i
s
1
9
6
9
p
s
i
(
9
.
0
p
p
g
E
M
W
)
;
w
i
l
l
d
r
i
l
l
w
/
8
.
0
p
p
g
u
s
i
n
g
M
P
D
t
o
h
o
l
d
1
0
.
0
p
p
g
a
t
s
h
o
e
28
Dr
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
29
BO
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
MP
S
P
i
s
1
5
4
9
p
s
i
g
;
w
i
l
l
t
e
s
t
B
O
P
s
t
o
3
5
0
0
p
s
i
g
;
i
n
i
t
t
i
a
l
B
O
P
t
e
s
t
t
o
5
0
0
0
p
s
i
g
30
BO
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
31
Ch
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
W
o
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
Ye
s
33
Is
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
34
Me
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
Ye
s
H2
S
n
o
t
a
n
t
i
c
i
p
a
t
e
d
35
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
Ma
x
i
m
u
m
p
o
r
e
p
r
e
s
s
u
r
e
o
f
~
9
.
1
p
p
g
e
i
n
N
a
r
w
h
a
l
r
e
s
e
r
v
o
i
r
.
M
P
D
t
o
~
1
0
.
0
p
p
g
b
e
u
t
i
l
i
z
e
d
i
n
p
r
o
d
u
c
t
i
o
n
s
e
c
t
i
o
n
.
36
Da
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
Se
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
Se
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
Co
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
9/
6
/
2
0
2
3
Ap
p
r
VT
L
Da
t
e
9/
2
9
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
9/
1
2
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
Tu
l
u
v
a
k
/
C
3
0
s
h
a
l
l
o
w
g
a
s
p
o
t
e
n
t
i
a
l
.
D
a
t
a
p
r
e
s
e
n
t
e
d
d
e
m
o
n
s
t
r
a
t
e
r
e
a
s
o
n
a
b
l
e
c
e
r
t
a
i
n
t
y
t
h
a
t
t
h
i
s
z
o
n
e
d
o
e
s
n
o
t
p
o
s
e
r
i
s
k
a
s
a
p
o
t
e
n
ti
a
l
l
y
hy
d
r
o
c
a
r
b
o
n
b
e
a
r
i
n
g
z
o
n
e
a
t
C
D
4
-
5
3
6
.
*&
:
JL
C
9
/
2
9
/
2
0
2
3
