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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
AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM
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'
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'
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-06-14_22171_CRU_CD4-587_ProductionProfile_Transmittal.docx
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AOGCC
Attn: Natural Resources Technician
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PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
223-098
T39024
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.06.25 12:59:43
-08'00'
Originated:Delivered to:12-Jun-24
Alaska Oil & Gas Conservation Commiss 12Jun24-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
CD4-587 50-103-20867-00-00 223-098 Colville River WL PPROF FINAL FIELD 29-Apr-24
2F-18 50-029-22720-00-00 Kuparuk River WL CBL FINAL FIELD 5-May-24
2F-18 50-029-22720-00-00 Kuparuk River WL GR FINAL FIELD 5-May-24
WD-02 50-103-20285-00-00 198-258 Colville River WL WFL FINAL FIELD 11-May-24
2N-310 50-103-20549-00-00 207-090 Kuparuk River WL Perforation FINAL FIELD 11-May-24
CD1-01A 50-103-20299-01-00 212-099 Colville River WL WFL FINAL FIELD 13-May-24
CD1-33A 50-103-20357-01-00 222-105 Colville River WL WFL FINAL FIELD 12-May-24
Transmittal Receipt
________________________________X__________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Ousidame@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
T38933
T38934
T38934
T38935
T38936
T38937
T38938
CD4-587 50-103-20867-00-00 223-098 Colville River WL PPROF FINAL FIELD 29-Apr-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.06.13 09:21:58 -08'00'
PTD: 223-098
T38507
2/15/2024Kayla Junke
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2024.02.15
14:12:52 -09'00'
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CD4-587 50-103-20867-00-00 223-098 COLVILLE RIVER MWD/LWD/DD VISION SERVICES FINAL FIELD 18-Dec-23 1
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CD4-587
PTD: 223-098
T38501
Kayla Junke
2/14/2024
Kayla
Junke
Digitally signed by Kayla Junke
Date: 2024.02.14 11:24:34 -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:CD4-587
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: CD4-587 e-transmittal well folder
Receipt: Date:
Alaska/IT Data Services-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 223-098
T38468
CD4-587
2/5/2024
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.05
10:38:43 -09'00'
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 20,669 feet feet
true vertical 4,195 feet feet
Effective Depth measured 20,669 feet 13,211 / 13,070 feet
true vertical 4,195 feet 4,024 / 4,006 feet
Perforation depth Measured depth N/A feet
True Vertical depth N/A feet
Tubing (size, grade, measured and true vertical depth)4.5" 12.6# L80 13,206' MD 4,023' TVD
SLZXP LTP 13,211' MD 4,024' TVD
Packers and SSSV (type, measured and true vertical depth)HAL TNT 13,070' MD 4,006' 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:Narwhal/ Qannik Oil Pool
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:Baskoro Tejo
Contact Email:Baskoro.Tejo@conocophillips.com
Authorized Title:Completion Engineer Contact Phone:907-265-6462
2397
Burst Collapse
2260
measured
TVD
Intermediate 2
Liner
9355
4390
11285
Casing
Structural
3453
4067
4-1/2"
9355
13597
20,492 4195
Plugs
Junk measured
2.283 MMlbs 20/40 Wan-Li Ceramic proppant, 69,000 lbs of 100 Mesh, and 3200 psi treating pressure/3500 psi BHG pressure.
Length
133
2864
133Conductor
Surface
Intermediate 1
20"
13-3/8"
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL384211, ADL380081, ADL391587
Colville Delta - Narwhal / Qannik Oil Pool
CD4-587
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-098
50-103-20867-00-00
P.O. Box 100360 Anchorage, AK 99510-03603. Address:
9-5/8"
11590
7-5/8"
5090
4790, 11080
8150
6890, 12620
NA
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing PressureGas-Mcf
MD
14,280' - 20,295' MD
Size
133
50202864
323-687
Sr Pet Eng:
9210
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.
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
TBD
p
k
ft
t
Fra
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223
6. A
G
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PG
,
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
January 26, 2024
By Grace Christianson at 7:48 am, Jan 26, 2024
CDW 01/26/2024
DSR-1/26/24
RBDMS JSB 013024
Sales Order#
Prepared By:
William Martin
James Campbell
Nannook Crew
5909066917
Intervals 1-17
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,
therefore, by the user of this report or any part thereof, is solely at the user’s own risk.
CD4-587
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20867
Prepared for: Baskoro Tejo
January 22, 2024
Narwal Formation
30# Delta
X0A0T
Table of Contents
Section Page(s)
Executive Summary
Actual Design
Wellbore Information
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
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 1-19
Water Straps 1-20
Water Straps 1-21
Water Straps 1-22
Water Analysis 1-17
Water Analysis 1-20
Water Analysis 1-21
Water Analysis 1-22
Real-Time QC
Event Log 1-19
Event Log 1-20
Event Log 1-21
Event Log 1-22
Prejob Break Test Day 1
Fann 15 Min Test Zone 1
Zone 2
Zone 3
Zone 4
Zone 5
Zone 6
Zone 7
Zone 8
Zone 9
Zone 10
Zone 11
Zone 12
Zone 13
Zone 14
Zone 15
Zone 16
Sand Sieve Analysis
100 - 102
94 - 99
87 - 93
3
4 - 7
8
46 - 48
49 - 51
52 - 58
9 - 30
31
32 - 42
43 - 45
59 - 61
62 - 64
84 - 86
65 - 67
68 - 74
75 - 77
78 - 80
81 - 83
103 - 105
106
107
108
109 - 112
113
114
115
116
117
118
119
120
121
122
123
124
125
126
127
128
129
130
131
132
133
134
135
136
137
143
138
139
140
141
142
X1A0T
Conoco Phillips - CD4-587 TOC 2
708,580 gallons of 30# Delta Frac
87,208 gallons of 30# Linear
0 gallons of Seawater
4,520 gallons of Freeze Protect
2,162,610 pounds of Wanli 20/40 Ceramic
72,000 pounds of 100M
767,195 gallons of 30# Delta Frac
98,419 gallons of 30# Linear
0 gallons of Seawater
6,930 gallons of Freeze Protect
2,283,600 pounds of Wanli 20/40 Ceramic
69,000 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 January 19, 2024 a stimulation treatment was performed in the Narwal formation on the CD4-587 well in Harrison Bay
County, AK. The CD4-587 was a 16 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 15 out of 16 stages. 0 stages were skipped, 0 stage screened out and 1 stages were cut
short of design. The actual treatment consisted of:
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 16 proppant fracs and 1 dart drop to open interval 17, all intervals were succesfully completed except
interval 15. The dart for interval 15 seated early and treated at a higher pressure than stage 14 so CoP made the decision to
flush the well and do a hard shut down for Momentum to read a signautre. After dropping another dart interval 15 was treating
at a higher pressure which led to the assumption that the darts had stacked, CoP made the decision to skip the interval.
Due to cutting interval 15 early. 70,000 lbs of proppant was left in the sand castle. The discrepency between the designed
20/40 and calculated pumped 20/40 is mainly due cutting interval 15 early and reverting interval 16 back to the 130,000 lb
design.
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.
All water analysis was within standard specifications. All tanks were successfully crosslinked in the lab before being pumped
downhole. Actual Crosslink samples from each interval were kept in a heat bath overnight to ensure they fully broke down. MO-
67 was diluted with a ratio of 1:3.
William Martin
Senior Technical Professional
Conoco Phillips - CD4-587 Executive Summary 3
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.29233121LEASECD4-587SALES ORDERBHST (°F)60LONG-150.9874292FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In-1-2 Freeze Protect Prime Up Pressure Test 5.0 1,000 630 15 151-3 Shut-In Shut-In-1-4 30# Linear Arsenal Sleeve Shift 5.0 1,260 159 4 4 1.50 30.00 2.00 0.151-5 30# Linear Spacer and Dart Drop 15.0 1,260 2,796 67 67 1.50 30.00 2.00 0.151-6 30# Linear Displace Dart to Seat 15.0 12,971 12,848 306 306 1.50 30.00 2.00 0.151-7 30# Delta Frac Minifrac - Establish Fluid 15.0 8,400 7,594 181 181 0.50 1.50 0.50 30.00 2.00 0.151-8 30# Delta Frac Minifrac - Treatment 23.0 6,300 6,379 152 152 0.50 1.50 0.50 30.00 2.00 0.151-9 30# Linear Minifrac - Flush 25.0 12,971 12,848 306 306 1.50 30.00 2.00 0.151-10 Shut-In Shut-In-1-11 30# Delta Frac Establish Stable Fluid 15.0 8,400 4,129 98 98 0.50 1.50 0.50 30.00 1.50 0.151-12 30# Delta Frac Pad 25.0 10,000 13,497 321 321 0.50 1.50 0.50 30.00 1.50 0.151-13 30# Delta Frac Conditioning Pad 100M 0.50 25.0 10,000 15,589 371 377 5,000 5,736 0.50 1.50 0.50 30.00 1.50 0.151-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 5,200 5,198 124 127 5,200 3,395 0.50 1.50 0.50 30.00 1.50 0.151-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 5,200 5,209 124 134 10,400 8,980 0.50 1.50 0.50 30.00 1.50 0.151-16 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 6,400 6,412 153 170 19,200 16,729 0.50 1.50 0.50 30.00 1.50 0.151-17 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 8,000 8,250 196 227 32,000 29,217 0.50 1.50 0.50 30.00 2.00 0.151-18 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 8,360 8,568 204 249 41,800 42,018 0.50 1.50 0.50 30.00 2.00 0.151-19 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,900 8,703 207 255 41,400 45,391 0.50 1.50 0.50 30.00 4.00 0.151-20 30# Delta Frac Spacer and Dart Drop 25.0 1,260 2,976 71 71 0.50 1.50 0.50 30.00 4.00 0.152-1 30# Delta Frac Pad 25.0 10,000 10,127 241 241 0.50 1.50 0.50 30.00 1.50 0.152-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 10,000 12,847 306 312 5,000 5,487 0.50 1.50 0.50 30.00 1.50 0.152-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 5,200 5,213 124 130 5,200 5,135 0.50 1.50 0.50 30.00 1.50 0.152-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 5,200 5,222 124 134 10,400 9,358 0.50 1.50 0.50 30.00 1.50 0.152-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 6,400 6,503 155 173 19,200 17,005 0.50 1.50 0.50 30.00 1.50 0.152-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 8,000 7,999 190 221 32,000 28,790 0.50 1.50 0.50 30.00 1.50 0.152-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 8,360 8,361 199 241 41,800 39,028 0.50 1.50 0.50 30.00 2.00 0.152-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,900 9,157 218 267 41,400 45,713 0.50 1.50 0.50 30.00 2.00 0.152-9 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,450 35 35 0.50 1.50 0.50 30.00 4.00 0.153-1 30# Delta Frac Pad 25.0 8,000 8,057 192 192 0.50 1.50 0.50 30.00 1.50 0.153-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 10,000 11,444 272 279 5,000 6,018 0.50 1.50 0.50 30.00 1.50 0.153-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,500 3,509 84 87 3,500 3,293 0.50 1.50 0.50 30.00 1.50 0.153-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 4,000 4,220 100 108 8,000 6,641 0.50 1.50 0.50 30.00 1.50 0.153-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 5,000 5,143 122 135 15,000 12,156 0.50 1.50 0.53 30.00 1.50 0.153-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,532 132 154 22,000 20,567 0.50 1.50 0.53 30.00 1.50 0.153-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 6,000 6,008 143 175 30,000 29,861 0.50 1.50 0.53 30.00 2.00 0.153-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,500 5,584 133 169 33,000 33,490 0.50 1.50 0.53 30.00 2.00 0.153-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 5,500 7,490 178 225 38,500 43,770 0.50 1.50 0.53 30.00 4.00 0.153-10 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,231 29 29 0.50 1.50 0.53 30.00 4.00 0.154-1 30# Delta Frac Pad 25.0 7,000 7,030 167 167 0.50 1.50 0.53 30.00 1.50 0.154-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 10,000 11,122 265 271 5,000 5,467 0.50 1.50 0.53 30.00 1.50 0.154-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,500 3,508 84 87 3,500 3,508 0.50 1.50 0.53 30.00 1.50 0.154-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 4,000 4,123 98 106 8,000 7,548 0.50 1.50 0.53 30.00 1.50 0.154-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,250 4,284 102 114 12,750 11,328 0.50 1.50 0.53 30.00 1.50 0.154-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,500 4,500 107 125 18,000 16,734 0.50 1.50 0.53 30.00 2.00 0.154-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,250 5,258125 151 26,250 24,396 0.50 1.50 0.53 30.00 2.00 0.154-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 5,323 127 159 30,000 30,305 0.50 1.50 0.53 30.00 2.000.154-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,500 4,511 107 140 31,500 31,080 0.50 1.50 0.53 30.00 2.000.154-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 4,190 100 125 20,000 23,748 0.50 1.50 0.53 30.00 4.000.154-11 30# Linear Flush 25.0 12,219 12,674 302 302 1.50 30.00 4.00 0.154-12 Shut-In Shut-In-Interval 1Narwhal@ 20293 - 20295.05 ft - °FInterval 2Narwhal@ 19898 - 19900.05 ft - °FInterval 3Narwhal@ 19508 - 19510.05 ft - °FInterval 4Narwhal@ 19116 - 19118.05 ft - °FLiquid Additives Dry Additives50-103-208675909066917Conoco Phillips - CD4-587Actual Design4
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.29233121LEASECD4-587SALES ORDERBHST (°F)60LONG-150.9874292FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid Additives Dry Additives50-103-2086759090669175-1 Shut-In Shut-In-5-2 Freeze Protect Prime Up Pressure Test 5.0 1,000 756 18 185-3 Shut-In Shut-In-5-4 30# Linear Spacer and Ball Drop 15.0 1,260 3,217 77 77 1.50 30.00 1.50 0.155-5 30# Delta Frac Establish Stable Fluid 15.0 8,400 5,910 141 141 0.50 1.50 0.50 30.00 1.50 0.155-6 30# Delta Frac Pad 25.0 4,500 5,653 135 135 0.50 1.50 0.50 30.00 1.50 0.155-7 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 13,548 323 328 4,000 5,350 0.50 1.50 0.50 30.00 1.50 0.155-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,000 2,031 48 50 2,000 1,732 0.50 1.50 0.50 30.00 1.50 0.155-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,000 2,011 48 51 4,000 2,606 0.50 1.50 0.45 30.00 1.50 0.155-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 2,400 2,809 67 72 7,200 5,065 0.50 1.50 0.45 30.00 1.50 0.155-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 3,500 3,497 83 96 14,000 11,982 0.50 1.50 0.45 30.00 2.00 0.155-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,510 5,502 131 159 27,550 26,035 0.50 1.50 0.45 30.00 2.00 0.155-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,750 4,762 113 142 28,500 26,998 0.50 1.50 0.45 30.00 2.00 0.155-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,261 78 102 22,750 23,135 0.50 1.50 0.45 30.00 2.00 0.155-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,000 5,257 125 162 24,000 34,275 0.50 1.50 0.45 30.00 4.00 0.155-16 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,550 37 37 0.50 1.50 0.45 30.00 4.00 0.156-1 30# Delta Frac Pad 25.0 4,500 4,398 105 105 0.50 1.50 0.45 30.00 1.50 0.156-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,080 192 197 4,000 3,901 0.50 1.50 0.45 30.00 1.50 0.156-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,000 2,009 48 50 2,000 1,775 0.50 1.50 0.45 30.00 1.50 0.156-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,000 2,009 48 51 4,000 3,355 0.50 1.50 0.45 30.00 1.50 0.156-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 2,400 2,453 58 66 7,200 6,889 0.50 1.50 0.45 30.00 1.50 0.156-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 3,500 3,513 84 97 14,000 12,946 0.50 1.50 0.45 30.00 2.00 0.156-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,510 5,515 131 159 27,550 26,425 0.50 1.50 0.45 30.00 2.00 0.156-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,750 4,752 113 144 28,500 28,972 0.50 1.50 0.45 30.00 2.00 0.156-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,258 78 102 22,750 22,873 0.50 1.50 0.45 30.00 2.00 0.156-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,000 4,412 105 133 24,000 26,655 0.50 1.50 0.45 30.00 4.00 0.156-11 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,607 38 38 0.50 1.50 0.45 30.00 4.00 0.157-1 30# Delta Frac Pad 25.0 4,500 4,779 114 114 0.50 1.50 0.45 30.00 1.50 0.157-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,551 204 208 4,000 4,166 0.50 1.50 0.45 30.00 1.50 0.157-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,000 2,036 48 51 2,000 2,021 0.50 1.50 0.45 30.00 1.50 0.157-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,000 2,016 48 52 4,000 3,456 0.50 1.500.45 30.00 1.50 0.157-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 2,400 2,405 57 64 7,200 6,595 0.50 1.500.45 30.00 1.50 0.157-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 3,500 3,499 83 97 14,000 12,789 0.50 1.500.45 30.00 2.00 0.157-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,510 5,519 131 159 27,550 26,135 0.50 1.500.45 30.00 2.00 0.157-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,750 4,736 113 142 28,500 27,377 0.501.50 0.45 30.00 2.00 0.157-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,267 78 102 22,750 22,723 0.501.50 0.45 30.00 2.00 0.157-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,000 4,921 117 148 24,000 29,428 0.501.50 0.45 30.00 4.00 0.157-11 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,502 36 36 0.50 1.50 0.45 30.00 4.00 0.158-1 30# Delta Frac Pad 25.0 2,600 2,422 58 58 0.50 1.50 0.45 30.00 1.50 0.158-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,633 206 209 4,000 3,586 0.501.50 0.45 30.00 1.50 0.158-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.0025.0 800 974 23 24 800 759 0.50 1.50 0.45 30.00 1.50 0.158-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.0025.0 1,200 1,200 29 30 2,400 1,366 0.50 1.50 0.45 30.00 1.50 0.158-530# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,600 1,604 38 42 4,800 3,946 0.50 1.50 0.45 30.00 1.50 0.158-630# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,970 1,973 47 54 7,880 6,946 0.50 1.50 0.45 30.00 2.00 0.158-730# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 3,210 3,222 77 93 16,050 14,996 0.50 1.50 0.45 30.00 2.00 0.158-830# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 3,550 3,554 85 106 21,300 20,135 0.50 1.50 0.45 30.00 2.00 0.158-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,760 90 117 22,750 25,709 0.50 1.50 0.45 30.00 2.00 0.158-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,940 3,946 94 126 31,520 30,403 0.50 1.50 0.45 30.00 4.00 0.158-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,500 4,027 96 124 22,500 26,548 0.50 1.50 0.45 30.00 4.00 0.158-12 30# Linear Flush 25.0 11,633 11,705 279 279 1.50 0.45 30.00 4.00 0.158-13 30# Linear Shut-In- 1.50 0.45 30.00 0.15Interval 6Narwhal@ 18329 - 18331.05 ft - °FInterval 7Narwhal@ 17939 - 17941.05 ft - °FInterval 8Narwhal@ 17543 - 17545.05 ft - °FInterval 5Narwhal@ 18724 - 18726.05 ft - °FConoco Phillips - CD4-587Actual Design5
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.29233121LEASECD4-587SALES ORDERBHST (°F)60LONG-150.9874292FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid Additives Dry Additives50-103-2086759090669179-1 Shut-In Shut-In-9-2 Freeze Protect Prime Up Pressure Test 5.0 1,260 1,344 32 329-3 Shut-In Shut-In-9-4 30# Linear Spacer and Dart Drop 15.0 1,260 4,954 118 118 1.50 30.00 2.00 0.159-5 30# Delta Frac Establish Stable Fluid 15.0 8,400 6,856 163 163 0.50 1.50 0.50 30.00 2.00 0.159-6 30# Delta Frac Pad 25.0 2,600 2,682 64 64 0.50 1.50 0.50 30.00 1.50 0.159-7 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 9,177 219 223 4,000 4,098 0.50 1.50 0.50 30.00 1.50 0.159-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 816 19 20 800 720 0.50 1.50 0.50 30.00 1.50 0.159-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,200 1,205 29 31 2,400 1,722 0.50 1.50 0.50 30.00 1.50 0.159-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,600 1,604 38 43 4,800 4,276 0.50 1.50 0.50 30.00 1.50 0.159-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,970 2,126 51 59 7,880 7,579 0.50 1.50 0.50 30.00 2.00 0.159-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 3,210 3,217 77 92 16,050 14,753 0.50 1.50 0.50 30.00 2.00 0.159-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 3,550 3,562 85 106 21,300 20,414 0.50 1.50 0.50 30.00 2.00 0.159-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 5,942 141 171 22,750 27,625 0.50 1.50 0.50 30.00 2.00 0.159-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,940 3,944 94 125 31,520 28,857 0.50 1.50 0.50 30.00 4.00 0.159-16 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,500 4,117 98 125 22,500 25,055 0.50 1.50 0.50 30.00 4.00 0.159-17 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,647 39 39 0.50 1.50 0.50 30.00 4.00 0.1510-1 30# Delta Frac Pad 25.0 2,600 2,852 68 68 0.50 1.50 0.50 30.00 1.50 0.1510-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,777 209 214 4,000 4,534 0.50 1.50 0.50 30.00 1.50 0.1510-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 928 22 23 800 802 0.50 1.50 0.50 30.00 1.50 0.1510-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,200 1,601 38 40 2,400 2,081 0.50 1.50 0.50 30.00 1.50 0.1510-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,600 7,142 170 189 4,800 18,011 0.50 1.50 0.50 30.00 1.50 0.1510-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,970 1,702 41 46 7,880 5,614 0.50 1.50 0.50 30.00 2.00 0.1510-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 3,210 2,912 69 84 16,050 13,423 0.50 1.50 0.50 30.00 2.00 0.1510-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 3,550 3,271 78 98 21,300 19,228 0.50 1.50 0.50 30.00 2.00 0.1510-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 2,802 67 88 22,750 19,597 0.50 1.50 0.50 30.00 2.00 0.1510-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,940 3,440 82 112 31,520 28,199 0.50 1.50 0.50 30.00 4.00 0.1510-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,500 3,773 90 115 22,500 23,688 0.50 1.50 0.50 30.00 4.00 0.1510-12 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,306 31 31 0.50 1.50 0.50 30.00 4.00 0.1511-1 30# Delta Frac Pad 25.0 1,940 1,962 47 47 0.50 1.50 0.50 30.00 1.50 0.1511-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,478 202 206 4,000 3,770 0.50 1.500.50 30.00 1.50 0.1511-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 798 19 20 800 625 0.50 1.500.50 30.00 1.50 0.1511-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,000 1,036 25 26 2,000 1,647 0.50 1.500.50 30.00 1.50 0.1511-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,200 1,209 29 32 3,600 3,258 0.50 1.500.50 30.00 1.50 0.1511-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,440 1,447 34 40 5,760 5,472 0.501.50 0.50 30.00 1.50 0.1511-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 2,400 2,392 57 70 12,000 11,912 0.501.50 0.50 30.00 2.00 0.1511-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 2,400 2,399 57 72 14,400 13,965 0.501.50 0.50 30.00 2.00 0.1511-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,150 3,152 75 97 22,050 20,954 0.50 1.50 0.50 30.00 2.00 0.1511-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,080 3,079 73 99 24,640 24,125 0.501.50 0.50 30.00 2.00 0.1511-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,750 2,752 66 93 24,750 25,806 0.501.50 0.50 30.00 4.00 0.1511-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 10.0025.0 2,000 3,651 87 107 20,000 18,627 0.50 1.50 0.50 30.00 4.00 0.1511-13 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,738 41 41 0.501.50 0.50 30.00 4.00 0.1512-130# Delta Frac Pad 25.0 1,940 1,875 45 45 0.50 1.50 0.50 30.00 1.50 0.1512-230# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,692 207 212 4,000 4,557 0.50 1.50 0.50 30.00 1.50 0.1512-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 789 19 20 800 735 0.50 1.50 0.50 30.00 1.50 0.1512-430# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,000 1,003 24 25 2,000 1,411 0.50 1.50 0.50 30.00 1.50 0.1512-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,200 1,439 34 38 3,600 3,549 0.50 1.50 0.50 30.00 1.50 0.1512-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,440 1,438 34 39 5,760 4,708 0.50 1.50 0.50 30.00 1.50 0.1512-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 2,400 2,405 57 69 12,000 10,805 0.50 1.50 0.50 30.00 2.00 0.1512-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 2,400 2,395 57 72 14,400 13,635 0.50 1.50 0.50 30.00 2.00 0.1512-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,150 3,198 76 100 22,050 22,164 0.50 1.50 0.50 30.00 2.00 0.1512-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,080 3,084 73 99 24,640 24,067 0.50 1.50 0.50 30.00 2.00 0.1512-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,750 2,736 65 91 24,750 24,768 0.50 1.50 0.50 30.00 4.00 0.1512-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 10.00 25.0 2,000 4,100 98 126 20,000 26,564 0.50 1.50 0.50 30.00 4.00 0.1512-13 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,332 32 32 0.50 1.50 0.50 30.00 4.00 0.1513-1 30# Delta Frac Pad 25.0 1,940 1,862 44 44 0.50 1.50 0.50 30.00 1.50 0.1513-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,090 193 198 4,000 4,562 0.50 1.50 0.50 30.00 1.50 0.1513-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 784 19 20 800 803 0.50 1.50 0.50 30.00 1.50 0.1513-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,000 1,016 24 26 2,000 1,593 0.50 1.50 0.50 30.00 1.50 0.1513-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,200 1,234 29 33 3,600 3,195 0.50 1.50 0.50 30.00 1.50 0.1513-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,440 1,451 35 40 5,760 5,187 0.50 1.50 0.50 30.00 1.50 0.1513-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 2,400 2,405 57 69 12,000 10,995 0.50 1.50 0.50 30.00 2.00 0.1513-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 2,400 2,401 57 72 14,400 13,749 0.50 1.50 0.50 30.00 2.00 0.1513-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,150 3,161 75 98 22,050 20,984 0.50 1.50 0.50 30.00 2.00 0.1513-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,080 3,082 73 99 24,640 24,335 0.50 1.50 0.50 30.00 2.00 0.1513-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,750 2,753 66 92 24,750 24,477 0.50 1.50 0.50 30.00 4.00 0.1513-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 10.00 25.0 2,000 4,051 96 125 20,000 26,470 0.50 1.50 0.50 30.00 4.00 0.1513-13 30# Linear Flush 25.0 10,927 10,974 261 261 1.50 30.00 4.00 0.1513-14 Shut-In Shut-In-Interval 9Narwhal@ 17191 - 17193.05 ft - °FInterval 10Narwhal@ 16797 - 16799.05 ft - °FInterval 11Narwhal@ 16443 - 16445.05 ft - °FInterval 12Narwhal@ 16088 - 16090.05 ft - °FInterval 13Narwhal@ 15734 - 15736.05 ft - °FConoco Phillips - CD4-587Actual Design6
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.29233121LEASECD4-587SALES ORDERBHST (°F)60LONG-150.9874292FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid Additives Dry Additives50-103-20867590906691714-1 Shut-In Shut-In-1.5014-2 Freeze Protect Prime Up Pressure Test 5.0 1,260 4,200 100 1001.5014-3 Shut-In Shut-In-1.5014-4 30# Linear Spacer and Dart Drop 15.0 1,260 2,106 50 50 1.50 30.00 1.50 0.1514-5 30# Delta Frac Establish Stable Fluid 15.0 8,400 7,878 188 188 0.50 1.50 0.50 30.00 1.50 0.1514-6 30# Delta Frac Pad 25.0 1,940 1,549 37 37 0.50 1.50 0.50 30.00 1.50 0.1514-7 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,016 191 194 4,000 2,981 0.50 1.50 0.50 30.00 2.00 0.1514-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 806 19 20 800 584 0.50 1.50 0.50 30.00 2.00 0.1514-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,000 1,008 24 25 2,000 1,294 0.50 1.50 0.50 30.00 2.00 0.1514-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,200 1,211 29 32 3,600 3,067 0.50 1.50 0.50 30.00 2.00 0.1514-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,440 1,421 34 39 5,760 5,140 0.50 1.50 0.50 30.00 4.00 0.1514-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 2,400 2,401 57 68 12,000 10,669 0.50 1.50 0.50 30.00 4.00 0.1514-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 2,400 2,398 57 72 14,400 13,970 0.50 1.50 0.50 30.00 4.00 0.1514-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,150 3,112 74 96 22,050 20,598 0.50 1.50 0.50 30.00 4.00 0.1514-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,080 3,083 73 99 24,640 23,730 0.50 1.50 0.50 30.00 2.00 0.1514-16 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,750 2,760 66 91 24,750 23,837 0.50 1.50 0.50 30.00 2.00 0.1514-17 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 10.00 25.0 2,000 3,861 92 121 20,000 27,123 0.50 1.50 0.50 30.00 2.00 0.1514-18 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,325 32 32 0.50 1.50 0.50 30.00 2.00 0.1515-1 30# Delta Frac Pad 25.0 1,940 2,126 51 51 0.50 1.50 0.50 30.00 1.50 0.1515-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 6,604 157 160 4,000 2,602 0.50 1.50 0.50 30.00 1.50 0.1515-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 793 19 20 800 709 0.50 1.50 0.50 30.00 1.50 0.1515-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,000 1,006 24 25 2,000 1,330 0.50 1.50 0.50 30.00 1.50 0.1515-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,200 1,203 29 32 3,600 2,967 0.50 1.50 0.50 30.00 1.50 0.1515-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,440 1,556 37 43 5,760 5,422 0.50 1.50 0.50 30.00 1.50 0.1515-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 2,400 2,400 57 68 12,000 10,454 0.50 1.50 0.50 30.00 2.00 0.1515-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 2,400 7,249 173 208 14,400 33,442 0.50 1.50 0.50 30.00 2.00 0.1515-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,150 - 22,050 0.50 1.50 0.50 30.00 2.00 0.1515-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,080 - 24,640 0.50 1.50 0.50 30.00 2.00 0.1515-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,750 - 24,750 0.50 1.50 0.50 30.00 4.00 0.1515-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 10.00 25.0 2,000 - 20,000 0.50 1.50 0.50 30.00 4.00 0.1515-13 30# Delta Frac Spacer and Dart Drop 25.0- 0.50 1.50 0.50 30.00 4.00 0.1515-14 30# Linear Flush 9,799 12,473 297 297 1.50 30.00 4.00 0.1515-15 Shut-In Shut-In--15-16 30# Linear Spacer and Dart Drop 15.0 1,260 1,599 38 38 1.50 30.00 1.50 0.1515-17 30# Delta Frac Establish Stable Fluid 15.0 8,400 3,683 88 88 0.50 1.50 0.50 30.00 1.50 0.1515-18 30# Delta Frac Pad 25.0 1,940 1,762 42 42 0.50 1.50 0.50 30.00 1.50 0.1515-19 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 4,817 115 117 4,000 2,200 0.50 1.50 0.50 30.00 1.50 0.1515-20 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 797 19 20 800 725 0.501.50 0.50 30.00 1.50 0.1515-21 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,000 8,596 205 219 2,000 13,539 0.501.50 0.50 30.00 1.50 0.1515-22 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,200 - 3,600 0.50 1.50 0.50 30.00 1.50 0.1515-23 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.0025.0 1,440 - 5,760 0.50 1.50 0.50 30.00 1.50 0.1515-2430# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 2,400 - 12,000 0.50 1.50 0.50 30.00 2.00 0.1515-2530# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 2,400 - 14,400 0.50 1.50 0.50 30.00 2.00 0.1515-26 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,150 - 22,050 0.50 1.50 0.50 30.00 2.00 0.1515-2730# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,080 - 24,640 0.50 1.50 0.50 30.00 2.00 0.1515-28 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 1,750 - 15,750 0.50 1.50 0.50 30.00 4.00 0.1515-29 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 10.00 25.0- 0.50 1.50 0.50 30.00 4.00 0.1515-30 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,350 32 32 0.50 1.50 0.50 30.00 4.00 0.1516-1 30# Delta Frac Pad 25.0 1,940 14,688 350 350 0.50 1.50 0.50 30.00 1.50 0.1516-2 30# Delta Frac Conditioning Pad 100M 0.50 25.0 8,000 8,149 194 198 4,000 3,400 0.50 1.50 0.50 30.00 1.50 0.1516-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 800 1,224 29 30 800 1,173 0.50 1.50 0.50 30.00 1.50 0.1516-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 1,000 1,020 24 26 2,000 1,704 0.50 1.50 0.50 30.00 1.50 0.1516-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 1,200 1,373 33 36 3,600 3,352 0.50 1.50 0.50 30.00 1.50 0.1516-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 1,440 1,455 35 40 5,760 5,298 0.50 1.50 0.50 30.00 1.50 0.1516-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 2,400 2,511 60 74 12,000 13,087 0.50 1.50 0.50 30.00 2.00 0.1516-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 2,400 2,399 57 73 14,400 14,545 0.50 1.50 0.50 30.00 2.00 0.1516-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,150 3,173 76 99 22,050 22,143 0.50 1.50 0.50 30.00 2.00 0.1516-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 3,080 3,083 73 100 24,640 25,145 0.50 1.50 0.50 30.00 2.00 0.1516-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 9.00 25.0 2,750 2,221 53 74 24,750 20,138 0.50 1.50 0.50 30.00 4.00 0.1516-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 10.00 25.0 2,000 3,814 91 119 20,000 26,332 0.50 1.50 0.50 30.00 4.00 0.1516-13 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,251 30 30 0.50 1.50 0.50 30.00 4.00 0.1517-1 30# Linear Displace Dart to Seat 25.0 9,128 10,066 240 240 1.50 30.00 4.00 0.1517-2 Shut-In Shut-In-811,138 872,544 20,775 23,079 2,333,000 2,168,395Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6708,580 767,195 2,162,610 2,095,980 2,283,600(gal) (gal) (gal) (lbs) (lbs) (lbs)87,208 98,419 72,000 72,415 69,000 Initial Design Material Volume 354.3 1,179.0 354.3 23,579.7 1,686.2 117.9- - - Actual Design Material Volume 383.6 1,298.4 384.0 25,968.4 1,873.4 129.84,520 6,930 - - - Physical Material Volume Pumped 363 1,285 384 25020 1,805 130- - - - - Physical Material Volume Deviance -5% -1% 0% -4% -4% 0%--** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 381 1,282 394 25,749 1,838 ---** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance -1% -1% 3% -1% -2% ---Interval 17Narwhal@ 14280 - 14282.05 ft - °FInterval 16Narwhal@ 14673 - 14675.05 ft - °FInterval 14Narwhal@ 15380 - 15382.05 ft - °F--- -Fluid Type30# Delta Frac30# LinearSeawaterFreeze Protect-Proppant TypeWanli 20/40 Ceramic100M--Conoco Phillips - CD4-587Actual Design7
Conoco Phillips NarwalCD4-58750-103-20867Description OD (in) ID (in) Wt (#) Grade FUF (gal/ft)MD Top (ft)MD Btm (ft) Volume (gal)Tubular Burst Pressure (psi)Tubing4.5 3.958 12.6 L-80 0.6392 0 13,109 8,379 8,430Tubing4.5 3.958 12.6 L-80 0.6392 13,109 20,492 4,719 8,430Total20,49213,098ft1.05ft60.0ftft1.05ft60.0ftTop MD (ft)Btm MD (ft)Average TVD (ft)Interval # Formation DescriptorAverage Interval Temperature (F)Ball Drop Time (HH:MM)Ball Hit Time (HH:MM)JSV Drop (bbl)JSV Slow Down (bbl)JSV Hit (bbl)Early (bbl)Surface Seat Pressure (psi)Surface Peak Pressure (psi)Surface Differential (psi)Rate at Shift (bpm)Toe20,293 20,295 -1Narwhal-10:14:00 AM 10:33:00 AM 61 320 350.00 19.8 1436 3263 1827 12.0019,898 19,900 -2Narwhal-1:39:00 PM 1:52:00 PM 3,022 3,275 3,31410.83,335 4,986 1,651 12.019,508 19,510 -3Narwhal-2:51:00 PM 3:03:00 PM 4,777 5,024 5,06211.92,847 4,748 1,901 12.019,116 19,118 -4Narwhal-3:55:00 PM 4:08:00 PM 6,329 6,570 6,60316.93,233 5,074 1,841 12.018,724 18,726 -5Narwhal-1:28:00 PM 1:45:00 PM 65 300 33020.02,254 4,162 1,908 12.318,329 18,331 -6Narwhal-2:34:00 PM 2:46:00 PM 1,550 1,779 1,81711.92,838 4,791 1,953 12.217,939 17,941 -7Narwhal-3:23:00 PM 3:34:00 PM 2,695 2,918 2,95216.03,061 5,057 1,996 12.017,543 17,545 -8Narwhal-4:12:00 PM 4:35:00 PM 3,868 4,085 4,12114.03,251 5,016 1,765 12.017,191 17,193 -9Narwhal-10:04:00 AM 10:21:00 AM 90 302 33714.61,981 2,593 612 12.216,797 16,799 -10Narwhal-11:02:00 AM 11:13:00 AM 1,379 1,585 1,61915.62,985 3,581 596 12.316,443 16,445 -11Narwhal-11:48:00 AM 11:58:00 AM 2,489 2,689 2,71920.23,076 4,596 1,520 11.616,088 16,090 -12Narwhal-12:28:00 PM 12:38:00 PM 3,438 3,633 3,6739.83,080 3,102 22 12.315,734 15,736 -13Narwhal-1:08:00 PM 1:18:00 PM 4,405 4,594 4,63014.52,975 4,686 1,711 10.915,380 15,382 -14Narwhal-9:29:00 AM 9:47:00 AM 40 224 2668.11,517 3,170 1,653 12.215,025 15,027 -15Narwhal-5:46:00 PM 6:01:00 PM 2,102 2,281 2,3237.72,046 3,857 1,811 12.314,673 14,675 -16Narwhal-6:20:00 PM 6:34:00 PM 2,617 2,790 2,83010.33,092 3,313 221 12.3Heel14,280 14,282 -17Narwhal-7:16:00 PM 7:26:00 PM 3,872 4,039 4,07910.32,046 2,159 113 12.3Temp. Gradient (°F/100 ft)BHST (°F)TVD at Bottom PerfMD at Bottom Perf020,295KOPAvg. TVDTotal MD789101123456171213141516Sleeve/Perf DepthSleeves239.5234.1228.7Interval #1Max Pressure (psi)6,500Isolation TypeSwell PackerTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data-2,23720,492Directional Data2,2371/19/2024KOPTemperature Data12,470 296.912,21911,96811,716Displacement to Top Sleeve/Perf (gal)(BBLS)12,971 308.812,719 302.8290.9285.0278.910,28310,0579,8319,6049,37911,46711,21310,98810,73710,5109,128273.0267.0261.6255.6250.2244.8223.3217.3X4A0TConoco Phillips - CD4-587 Wellbore Information8
1/19/24 10:04
1/19/24 13:39
215 min
12.0 bpm
3,263 psi
0 psi
20 bbl
25.7 bpm
4,012 psi
NA psi
23.8 bpm
3,421 psi
3,364 psi
NA psi
1,998 hhp
717 psi
0 psi
0 psi
6.35 ppg
5
5
30 %
38 %
27 cP
72.9 F
8.5
MiniFrac
21.020 bpm
2139 psi
nA psi
25.47 bpm
2466 psi
NA psi
1031 psi
145,730 lbs
5,736 lbs
151,466 lbs
151,424 lbs
92,504 gal 2,202 bbls
28,651 gal 682 bbls
0 gal 0 bbls
630 gal 15 bbls
Minifrac Max Surface Pressure:
100M Pumped:
Proppant in Formation:
30# Delta Frac Volume:
30# Linear Volume:
Seawater Volume:
Minifrac Max DH Pressure:
Dart/Ball Early :
Average pH:
Minifrac Average Rate:
Pump Time:
Pad Percentage Actual
Wanli 20/40 Ceramic Pumped:
Diagnostic method
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
CD4-587 - 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:
Minifrac Max Rate:
ISIP
Proppant Summary
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Freeze Protect Volume:
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Conoco Phillips - CD4-587 Interval Summary 9
12,848 gal 306 bbls
13,497 gal 321 bbls
15,589 gal 371 bbls
42,340 gal 1,008 bbls
5,772 gal 137 bbls
0 gal 0 bbls
0 gal 0 bbls
4,129 gal 98 bbls
7,594 gal 181 bbls
6,379 gal 152 bbls
12,848 gal 306 bbls
159 gal 4 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Displace Dart to Seat Volume:
Pad Volume:
Minifrac - Establish Fluid Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Shifted the Aresenal sleeve at 5,350 psi. MiniFrac was pumped and the decision was made to
pump the job as per design. During the first 20/40 sand stage, there were issues with frozen
sand obstructing the screws. Designed sand concetration was hard to reach during 4 and 5 ppg
sand but during 6 ppg sand, the blockage cleared itself. The stage was pumped without any
modifications.
Minifrac - Flush Volume:
Arsenal Sleeve Shift Volume:
Greg Clayton
Willie Martin
Minifrac - Treatment Volume:
Fluid Summary (by stage description)
Flush Volume:
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.
Spacer and Dart Drop Volume:
Spacer and Ball Drop Volume:
Interval Status:
Nate Brzezinski
James Campell
Conoco Phillips - CD4-587 Interval Summary 10
1/19/24 13:39
1/19/24 14:51
72 min
12.0 bpm
4,986 psi
0 psi
11 bbl
25.7 bpm
3,670 psi
NA psi
24.5 bpm
3,366 psi
3,296 psi
NA psi
2,024 hhp
445 psi
474 psi
6.14 ppg
5
5
30 %
32 %
27 cP
75.5 F
8.5
145,029 lbs
5,487 lbs
150,516 lbs
150,468 lbs
66,879 gal 1,592 bbls
10,127 gal 241 bbls
12,847 gal 306 bbls
42,455 gal 1,011 bbls
1,450 gal 35 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Pad Percentage Design
Pad Percentage Actual
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
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:
CD4-587 - 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
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
30# Delta Frac Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Interval Status:
The stage was pumped as per design, there were no issues achieving the designed sand
concetration
*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
Willie Martin
Nate Brzezinski
James Campell
Conoco Phillips - CD4-587 Interval Summary 11
4,986
1/19/24 14:51
1/19/24 15:55
64 min
12.0 bpm
4,748 psi
0 psi
12 bbl
25.7 bpm
3,666 psi
NA psi
24.3 bpm
3,091 psi
3,019 psi
NA psi
1,837 hhp
450 psi
470 psi
7.32 ppg
5
5
30 %
31 %
27 cP
71.8 F
8.3
149,778 lbs
6,018 lbs
155,796 lbs
155,692 lbs
58,218 gal 1,386 bbls
8,057 gal 192 bbls
11,444 gal 272 bbls
37,486 gal 893 bbls
1,231 gal 29 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Summary
Spacer and Ball Drop Volume:
Wanli 20/40 Ceramic Pumped:
Pad Volume:
Average Visc:
Initial OA Pressure:
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
Initial Surface Pressure (Breakdown):
Start Date/Time:
CD4-587 - 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:
30# Delta Frac Volume:
Willie Martin
Nate Brzezinski
James Campell
Interval Status:
The stage was pumped to completion as per design. There was good signature from dart
indicated a good shift.
*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 - CD4-587 Interval Summary 12
1/19/24 15:55
1/19/24 17:07
72 min
12.0 bpm
5,074 psi
0 psi
17 bbl
25.9 bpm
3,780 psi
NA psi
24.9 bpm
3,444 psi
3,371 psi
NA psi
2,103 hhp
444 psi
474 psi
8.31 ppg
5
5
30.0 %
30.3 %
27 cP
74.1 F
8.5
920 psi
913 psi
902 psi
894 psi
148,647 lbs
5,467 lbs
154,114 lbs
154,114 lbs
53,849 gal 1,282 bbls
12,674 gal 302 bbls
Fluid Summary (by fluid description)
Initial Rate (Breakdown):
Proppant in Formation:
Max Surface Pressure:
30# Delta Frac Volume:
30# Linear 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:
CD4-587 - 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:
Final 5 min:
100M Pumped:
ISIP
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Final 10 min:
Final 15 min:
Average Temp:
Average pH:
Initial OA Pressure:
Conoco Phillips - CD4-587 Interval Summary 13
5,074
7,030 gal 167 bbls
11,122 gal 265 bbls
35,697 gal 850 bbls
12,674 gal 302 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.
Flush Volume:
Interval 4 was pumped to completion without any operational issues. This was the final stage
on day 1 of pumping.
James Campell
Pad Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Interval Status:
Greg Clayton
Willie Martin
Nate Brzezinski
Conoco Phillips - CD4-587 Interval Summary 14
1/20/24 13:23
1/20/24 14:46
83 min
12.3 bpm
4,162 psi
0 psi
20 bbl
26.1 bpm
4,162 psi
NA psi
21.5 bpm
2,834 psi
2,789 psi
NA psi
1,493 hhp
531 psi
330 psi
379 psi
8.34 ppg
5
4
28 %
36 %
27 cP
74.1 F
8.4
131,828 lbs
5,350 lbs
137,178 lbs
137,080 lbs
55,791 gal 1,328 bbls
3,217 gal 77 bbls
756 gal 18 bbls
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Temp:
Initial Surface Pressure (Breakdown):
Max Rate:
Total Proppant Pumped* :
Initial Rate (Breakdown):
Pumps Starting Stage:
Pumps Ending Stage:
Pump Time:
30# Delta Frac Volume:
Average pH:
Pad Percentage Actual
CD4-587 - Narwal - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Pad Percentage Design
Average Rate:
Proppant in Formation:
Average Missile HHP:
Open Well Pressure:
Average Visc:
Max Surface Pressure:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Wanli 20/40 Ceramic Pumped:
Freeze Protect Volume:
30# Linear Volume:
100M Pumped:
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
Conoco Phillips - CD4-587 Interval Summary 15
5,653 gal 135 bbls
13,548 gal 323 bbls
29,130 gal 694 bbls
1,550 gal 37 bbls
3,217 gal 77 bbls
5,910 gal 141 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Nate Brzezinski
During 2-3 ppg 20/40, there were issues with the castle gate which caused prop concentration
to run lower than designed, after it was fixed concentration matched design. Pump 621 was
swapped with 458 due to a rock on 621.
Greg Clayton
James Campell
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
Spacer and Dart Drop Volume:
Proppant Laden Fluid Volume:
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.
Pad Volume:
Willie Martin
Fluid Summary (by stage description)
Conditioning Pad Volume:
Conoco Phillips - CD4-587 Interval Summary 16
1/20/24 14:46
1/20/24 15:36
50 min
12.2 bpm
4,791 psi
0 psi
12 bbl
25.8 bpm
3,874 psi
NA psi
24.0 bpm
3,442 psi
3,392 psi
NA psi
2,025 hhp
365 psi
396 psi
8.00 ppg
4
4
28 %
27 %
26 cP
74.1 F
8.4
129,890 lbs
3,901 lbs
133,791 lbs
133,757 lbs
42,006 gal 1,000 bbls
4,398 gal 105 bbls
8,080 gal 192 bbls
27,921 gal 665 bbls
1,607 gal 38 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Proppant Concentration:
Pad Percentage Actual
Max OA Pressure:
Spacer and Dart Drop Volume:
Proppant Laden Fluid Volume:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Pad Volume:
Wanli 20/40 Ceramic Pumped:
Pad Percentage Design
Average Temp:
Total Proppant Pumped* :
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Initial OA Pressure:
Start Date/Time:
30# Delta Frac Volume:
Average Surface Pressure:
Average BH Pressure:
100M Pumped:
Pumps Ending Stage:
Conditioning Pad Volume:
Interval Status:
Average Visc:
Proppant in Formation:
During the 7ppg sand stage, a pump kicked out due to the pre-load pressure, it was brought
back up and the stage was resumed as per design.
Willie Martin
Nate Brzezinski
James Campell
*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
CD4-587 - Narwal - Interval 6
Interval Summary
Average pH:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Pumps Starting Stage:
Max Rate:
Average Missile Pressure:
Average Rate:
Pump Time:
Initial Rate (Breakdown):
Average Missile HHP:
Conoco Phillips - CD4-587 Interval Summary 17
1/20/24 15:36
1/20/24 16:25
49 min
12.0 bpm
5,057 psi
0 psi
16 bbl
25.7 bpm
3,756 psi
NA psi
23.0 bpm
3,423 psi
3,372 psi
NA psi
1,927 hhp
386 psi
405 psi
7.92 ppg
4
4
28 %
28 %
26 cP
74 F
8.4
130,524 lbs
4,166 lbs
134,690 lbs
134,667 lbs
43,231 gal 1,029 bbls
0 gal 0 bbls
4,779 gal 114 bbls
8,551 gal 204 bbls
28,399 gal 676 bbls
1,502 gal 36 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant in Formation:
Proppant Laden Fluid Volume:
Conditioning Pad Volume:
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.
Average BH Pressure:
Average Surface Pressure:
Wanli 20/40 Ceramic Pumped:
Average Visc:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Average Temp:
Average Missile HHP:
Average pH:
Max Proppant Concentration:
CD4-587 - 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:
Displace Dart to Seat Volume:
Pad Volume:
100M Pumped:
Pump Time:
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Interval Summary
Interval Status:
Stage pumped as per design.
Fluid Summary (by fluid description)
30# Delta Frac Volume:
Greg Clayton
Willie Martin
James Campell
Fluid Summary (by stage description)
Nate Brzezinski
Spacer and Dart Drop Volume:
Conoco Phillips - CD4-587 Interval Summary 18
1/20/24 16:25
1/20/24 17:06
41 min
12.0 bpm
5,016 psi
0 psi
14 bbl
25.9 bpm
3,704 psi
3,766 psi
24.8 bpm
3,346 psi
3,293 psi
NA psi
2,031 hhp
391 psi
412 psi
9.14 ppg
4
4
28 %
27 %
26 cP
73.3 F
8.4
884 psi
911 psi
901 psi
891 psi
130,808 lbs
3,586 lbs
134,394 lbs
134,394 lbs
35,315 gal 841 bbls
11,705 gal 279 bbls
2,422 gal 58 bbls
8,633 gal 206 bbls
24,260 gal 578 bbls
11,705 gal 279 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Flush Volume:
Max BH Pressure:
Dart/Ball Early :
End Date/Time:
Pump Time:
Average Rate:
Max Proppant Concentration:
Average BH Pressure:
Max OA Pressure:
Pumps Ending Stage:
Stage was pumped as per design. This was the final stage of pumping for day 2.
Proppant Laden Fluid Volume:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Average Missile Pressure:
Initial Rate (Breakdown):
Max Surface Pressure:
Average pH:
Average Surface Pressure:
Pumps Starting Stage:
ISIP
*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 Rate:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Fluid Summary (by fluid description)
Pad Volume:
Average Visc:
Total Proppant Pumped* :
30# Linear Volume:
Final 5 min:
Final 15 min:
Conditioning Pad Volume:
Average Missile HHP:
Fluid Summary (by stage description)
Interval Summary
CD4-587 - Narwal - Interval 8
Pad Percentage Actual
Pad Percentage Design
Proppant in Formation:
Final 10 min:
Average Temp:
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Proppant Summary
30# Delta Frac Volume:
Interval Status:
Willie Martin
Greg Clayton
Nate Brzezinski
James Campell
Conoco Phillips - CD4-587 Interval Summary 19
1/21/24 9:58
1/21/24 11:13
75 min
12.2 bpm
2,593 psi
0 psi
15 bbl
26.3 bpm
3,408 psi
NA psi
24.7 bpm
3,037 psi
2,974 psi
NA psi
1,840 hhp
451 psi
25 psi
318 psi
8.72 ppg
5
5
26 %
27 %
26 cP
75.2 F
8.4
131,001 lbs
4,098 lbs
135,099 lbs
135,023 lbs
46,895 gal 1,117 bbls
4,954 gal 118 bbls
1,344 gal 32 bbls
2,682 gal 64 bbls
9,177 gal 219 bbls
26,533 gal 632 bbls
6,601 gal 157 bbls
6,856 gal 163 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Pad Volume:
Average Missile HHP:
Initial OA Pressure:
Average Rate:
100M Pumped:
Pad Percentage Actual
While establishing XL, the MO-67 line froze and took a few minutes to unfreeze. After
establishing good XL, stage was resumed to design. During 3 ppg sand stage, pump 621 lost
some rate, brought back up and stage continued. During the 7 ppg sand stage, plastic debris
was noticed in the hopper which caused the sand concetration to lower.
Proppant in Formation:
Max OA Pressure:
Average BH Pressure:
James Campell
Interval Summary
Open Well Pressure:
Dart/Ball Early :
Average Visc:
Pad Percentage Design
Total Proppant Pumped* :
Max Surface Pressure:
Max BH Pressure:
Initial Rate (Breakdown):
Max Rate:
Pumps Ending Stage:
Initial Surface Pressure (Breakdown):
Proppant Summary
Wanli 20/40 Ceramic Pumped:
Average Missile Pressure:
Establish Stable Fluid Volume:
Spacer and Dart Drop Volume:
30# Delta Frac Volume:
30# Linear Volume:
CD4-587 - Narwal - Interval 9
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Initial BH Pressure (Breakdown):
Freeze Protect Volume:
Fluid Summary (by stage description)
Average pH:
Fluid Summary (by fluid description)
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.
Willie Martin
Nate Brzezinski
Average Temp:
Max Proppant Concentration:
Pumps Starting Stage:
Average Surface Pressure:
Greg Clayton
Conoco Phillips - CD4-587 Interval Summary 20
1/21/24 11:13
1/21/24 11:58
45 min
12.3 bpm
3,581 psi
0 psi
16 bbl
26.1 bpm
3,555 psi
NA psi
24.3 bpm
3,170 psi
3,105 psi
NA psi
1,891 hhp
353 psi
364 psi
9.21 ppg
5
5
28 %
26 %
25 cP
77 F
8.5
130,643 lbs
4,534 lbs
135,177 lbs
135,053 lbs
40,506 gal 964 bbls
2,852 gal 68 bbls
8,777 gal 209 bbls
27,571 gal 656 bbls
1,306 gal 31 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
100M Pumped:
Pad Volume:
Conditioning Pad Volume:
Fluid Summary (by stage description)
Willie Martin
Initial Rate (Breakdown):
Average Surface Pressure:
Spacer and Dart Drop Volume:
Average Temp:
Max Surface Pressure:
Max BH Pressure:
Pumps Ending Stage:
Initial Surface Pressure (Breakdown):
Proppant Summary
Average Missile Pressure:
Average Rate:
Max Rate:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Average Missile HHP:
Wanli 20/40 Ceramic Pumped:
Initial OA Pressure:
Max Proppant Concentration:
Proppant Laden Fluid Volume:
During 2 ppg sand, ADP lost suction for a minute. Holding tank was full and job resumed after
gel was confirmed good in the lab. Stage pumped to completion
Interval Summary
Pump Time:
Start Date/Time:
CD4-587 - Narwal - Interval 10
End Date/Time:
Initial BH Pressure (Breakdown):
Pad Percentage Actual
Pumps Starting Stage:
Dart/Ball Early :
30# Delta Frac Volume:
Average Visc:
Pad Percentage Design
Max OA Pressure:
Average pH:
Average BH Pressure:
Nate Brzezinski
James Campell
*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 - CD4-587 Interval Summary 21
1/21/24 11:58
1/21/24 12:38
40 min
11.6 bpm
4,596 psi
0 psi
20 bbl
26.1 bpm
3,723 psi
NA psi
24.1 bpm
3,225 psi
3,158 psi
NA psi
1,905 hhp
364 psi
393 psi
10.10 ppg
5
5
28 %
28 %
25 cP
76.3 F
8.6
126,391 lbs
3,770 lbs
130,161 lbs
130,161 lbs
34,093 gal 812 bbls
1,962 gal 47 bbls
8,478 gal 202 bbls
21,915 gal 522 bbls
1,738 gal 41 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Surface Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Average Missile Pressure:
Start Date/Time:
Interval Status:
Average Missile HHP:
Pumps Starting Stage:
100M Pumped:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Willie Martin
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:
CD4-587 - Narwal - Interval 11
End Date/Time:
Max Proppant Concentration:
Average Visc:
Average Temp:
Max Rate:
Wanli 20/40 Ceramic Pumped:
Average pH:
Pad Percentage Actual
Initial OA Pressure:
Nate Brzezinski
James Campell
*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:
Max BH Pressure:
Average Rate:
Average BH Pressure:
Fluid Summary (by stage description)
Pad Volume:
Spacer and Dart Drop Volume:
During 10 ppg sand, the bin went empty right at the end of the stage and the hopper was lost
and then brought back up, all 20/40 had to be cleared. Stage pumped to completion.
Greg Clayton
Conoco Phillips - CD4-587 Interval Summary 22
1/21/24 12:38
1/21/24 13:18
40 min
12.3 bpm
3,102 psi
0 psi
10 bbl
26.1 bpm
3,484 psi
NA psi
24.2 bpm
3,125 psi
3,064 psi
NA psi
1,850 hhp
375 psi
393 psi
9.94 ppg
5
5
28 %
27 %
26 cP
75.7 F
8.5
132,406 lbs
4,557 lbs
136,963 lbs
136,906 lbs
34,486 gal 821 bbls
1,875 gal 45 bbls
8,692 gal 207 bbls
22,587 gal 538 bbls
1,332 gal 32 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant in Formation:
Total Proppant Pumped* :
100M Pumped:
Pad Percentage Design
Max Surface Pressure:
Wanli 20/40 Ceramic Pumped:
Pumps Ending Stage:
Proppant Laden Fluid Volume:
Average Temp:
Interval Status:
Pad Volume:
Conditioning Pad Volume:
Spacer and Dart Drop Volume:
James Campell
*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.
Proppant Summary
Fluid Summary (by fluid description)
30# Delta Frac Volume:
Fluid Summary (by stage description)
Start Date/Time:
Average Rate:
Average Missile Pressure:
Pad Percentage Actual
Initial Rate (Breakdown):
Average BH Pressure:
Stage was pumped as per design.Willie Martin
Average Surface Pressure:
Dart/Ball Early :
Max BH Pressure:
Average Visc:
Nate Brzezinski
Greg Clayton
Max OA Pressure:
Average pH:
Max Rate:
Initial OA Pressure:
End Date/Time:
Pumps Starting Stage:
Max Proppant Concentration:
Pump Time:
CD4-587 - Narwal - Interval 12
Interval Summary
Initial BH Pressure (Breakdown):
Average Missile HHP:
Initial Surface Pressure (Breakdown):
Conoco Phillips - CD4-587 Interval Summary 23
1/21/24 13:18
1/21/24 13:56
38 min
10.9 bpm
4,686 psi
0 psi
14 bbl
26.2 bpm
3,283 psi
NA psi
25.2 bpm
3,059 psi
3,000 psi
NA psi
1,886 hhp
370 psi
393 psi
10.14 ppg
5
5
28 %
26 %
27 cP
75.3 F
8.5
909 psi
909.3 psi
891.8 psi
882.6 psi
131,788 lbs
4,562 lbs
136,350 lbs
136,350 lbs
100M Pumped:
Proppant in Formation:
Max Rate:
Wanli 20/40 Ceramic Pumped:
Average BH Pressure:
Average Temp:
Pumps Ending Stage:
Average Surface Pressure:
Start Date/Time:
Pumps Starting Stage:
Average Rate:
Proppant Summary
Dart/Ball Early :
Max OA Pressure:
Average Visc:
Average pH:
Initial OA Pressure:
Max BH Pressure:
Initial BH Pressure (Breakdown):
Average Missile Pressure:
Pump Time:
CD4-587 - Narwal - Interval 13
Final 5 min:
Final 10 min:
Pad Percentage Design
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Max Proppant Concentration:
ISIP:
Average Missile HHP:
Interval Summary
End Date/Time:
Total Proppant Pumped* :
Pad Percentage Actual
Final 15 min:
Conoco Phillips - CD4-587 Interval Summary 24
32,290 gal 769 bbls
10,974 gal 261 bbls
0 gal 0 bbls
1,862 gal 44 bbls
8,090 gal 193 bbls
22,338 gal 532 bbls
10,974 gal 261 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
30# Delta Frac Volume:
Pad Volume:
Displace Dart to Seat 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.Greg Clayton
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Interval 13 was pumped as per design with no operational issues. This was the last stage of
Day 3 of pumping.
Willie Martin
Nate Brzezinski
James Campell
Fluid Summary (by fluid description)
30# Linear Volume:
Conoco Phillips - CD4-587 Interval Summary 25
1/22/24 9:25
1/22/24 10:24
59 min
12.2 bpm
3,170 psi
0 psi
8 bbl
26.0 bpm
3,351 psi
NA psi
24.1 bpm
2,723 psi
2,676 psi
NA psi
1,605 hhp
432 psi
0 psi
429 psi
9.66 ppg
5
5
28 %
26 %
26 cP
71.8 F
8.5
130,012 lbs
2,981 lbs
132,993 lbs
132,922 lbs
40,829 gal 972 bbls
2,106 gal 50 bbls
4,200 gal 100 bbls
1,549 gal 37 bbls
8,016 gal 191 bbls
22,061 gal 525 bbls
3,431 gal 82 bbls
7,878 gal 188 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Rate:
Average Missile Pressure:
Pumps Ending Stage:
Interval Status:
Initial BH Pressure (Breakdown):
Establish Stable Fluid Volume:
Average Surface Pressure:
Pad Percentage Design
Pad Percentage Actual
Initial Rate (Breakdown):
Willie Martin
100M Pumped:
End Date/Time:
Average Temp:
Dart/Ball Early :
Max Surface Pressure:
Max OA Pressure:
Max Proppant Concentration:
Proppant Summary
Greg Clayton
During 4 ppg sand stage, one pump kicked out due to the pre-load
Pump Time:
Average pH:
Wanli 20/40 Ceramic Pumped:
Max Rate:
Max BH Pressure:
CD4-587 - Narwal - Interval 14
Average Visc:
Initial OA Pressure:
Fluid Summary (by stage description)
Nate Brzezinski
James Campell
*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 Summary
Start Date/Time:
Average Missile HHP:
Open Well Pressure:
Pumps Starting Stage:
Average BH Pressure:
Initial Surface Pressure (Breakdown):
Total Proppant Pumped* :
30# Linear Volume:
Proppant Laden Fluid Volume:
Pad Volume:
Proppant in Formation:
Fluid Summary (by fluid description)
Freeze Protect Volume:
30# Delta Frac Volume:
Spacer and Dart Drop Volume:
Conditioning Pad Volume:
Conoco Phillips - CD4-587 Interval Summary 26
1/22/24 17:42
1/22/24 18:34
52 min
12.3 bpm
3,857 psi
0 psi
8 bbl
15.9 bpm
4,265 psi
NA psi
15.2 bpm
3,586 psi
3,533 psi
NA psi
1,333 hhp
436 psi
420 psi
467 psi
1.89 ppg
5
5
35 %
37 %
25 cP
70.4 F
8.5
68,588 lbs
4,802 lbs
73,390 lbs
73,390 lbs
43,942 gal 1,046 bbls
14,072 gal 335 bbls
Average Rate:
Start Date/Time:
30# Delta Frac Volume:
Pumps Starting Stage:
Fluid Summary (by fluid description)
Average Visc:
Average pH:
100M Pumped:
30# Linear Volume:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Average Temp:
Open Well Pressure:
Average Surface Pressure:
Wanli 20/40 Ceramic Pumped:
Max Surface Pressure:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pump Time:
Initial Rate (Breakdown):
Average Missile HHP:
Dart/Ball Early :
CD4-587 - 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:
Conoco Phillips - CD4-587 Interval Summary 27
3,888 gal 93 bbls
11,421 gal 272 bbls
23,600 gal 562 bbls
2,949 gal 70 bbls
12,473 gal 297 bbls
3,683 gal 88 bbls
Cut Short
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Greg Clayton
Proppant Laden Fluid Volume:
Spacer and Dart Drop Volume:
Fluid Summary (by stage description)
Dart signature was early. During 5 ppg sand stage decision was made to flush the well and
shut down to get a signature for Momentum. Momentum's signature indicated the dart seated
at the same place for interval 14. As a result, crew freeze protected the lines to load more
water before resuming pumping. Crew shut down until more water could be loaded to finish
pumping. Stage was resumed with a modified design to account for the 60,000lb that was
presumably pumped into interval 14. After re filling the water tanks, another dart was dropped,
the signature showed that the dart stacked and Momentum calculated that the dart seating at
interval 15. Decision was made to cut sand and drop the dart for stage 16.
*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.
Establish Stable Fluid Volume:
Flush Volume:
Willie Martin
Nate Brzezinski
James Campell
Conditioning Pad Volume:
Interval Status:
Pad Volume:
Conoco Phillips - CD4-587 Interval Summary 28
1/22/24 18:34
1/22/24 19:26
52 min
12.3 bpm
3,313 psi
0 psi
10 bbl
26.0 bpm
3,590 psi
NA psi
24.3 bpm
3,132 psi
3,077 psi
NA psi
1,865 hhp
427 psi
449 psi
10.12 ppg
5
5
32 %
45 %
25 cP
77.5 F
8.5
132,917 lbs
3,400 lbs
136,317 lbs
136,317 lbs
46,361 gal 1,104 bbls
14,688 gal 350 bbls
8,149 gal 194 bbls
22,273 gal 530 bbls
1,251 gal 30 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by stage description)
Total Proppant Pumped* :
Interval Status:
Interval 16 was originally planned as a 100k lb design due to pumping the 60k lbs during
interval 15 attempt 1. However, due to not pumping all of the designed proppant on interval 15
attempt 2, the design was reverted back to the original 130k lb design. 100 Mesh sand stage
was extended to pump the remaining 100 Mesh on location. There was 70k lbs left in the sand
castle.
Wanli 20/40 Ceramic Pumped:
Average Temp:
Proppant in Formation:
Spacer and Dart Drop Volume:
100M Pumped:
30# Delta Frac Volume:
Pad Volume:
Average Surface Pressure:
Fluid Summary (by fluid description)
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Interval Summary
Pad Percentage Actual
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Missile HHP:
Max OA Pressure:
CD4-587 - Narwal - Interval 16
Max Rate:
End Date/Time:
Max BH Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Average pH:
Pumps Starting Stage:
Start Date/Time:
Average BH Pressure:
Average Rate:
Pumps Ending Stage:
Max Surface Pressure:
Average Missile Pressure:
Proppant Summary
Max Proppant Concentration:
Pad Percentage Design
Average Visc:
Pump Time:
Willie Martin
Nate Brzezinski
James Campell
*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 - CD4-587 Interval Summary 29
1/22/24 19:26
1/22/24 19:29
3 min
12.3 bpm
2,159 psi
0 psi
10 bbl
12.3 bpm
2,334 psi
2,212 psi
12.3 bpm
2,039 psi
2,009 psi
NA psi
613 hhp
448 psi
493 psi
0.00 ppg
5
5
25 cP
74 F
8.4
758 psi
817 psi
814 psi
811 psi
0 lbs
0 lbs
0 lbs
0 lbs
0 gal 0 bbls
10,066 gal 240 bbls
0 gal 0 bbls
0 gal 0 bbls
10,066 gal 240 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Rep:
Average Visc:
Average Temp:
Max OA Pressure:
Average Surface Pressure:
Max Rate:
Initial OA Pressure:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Pumps Starting Stage:
Average Missile HHP:
Pump Time:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Interval Status:
Pumps Ending Stage:
Displace Dart to Seat Volume:
Average BH Pressure:
Seawater Volume:
Final 15 min:
Total Proppant Pumped* :
Fluid Summary (by stage description)
Interval 17 was only a dart drop. Signature was small but on time. Willie Martin
Nate Brzezinski
James Campell
Start Date/Time:
End Date/Time:
Max Proppant Concentration:
100M Pumped:
Fluid Summary (by fluid description)
Wanli 20/40 Ceramic Pumped:
Final 10 min:
30# Delta Frac Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of eight ticket ol mes and ma ar slightl from this n mber
Freeze Protect Volume:
30# Linear Volume:
Greg Clayton
Average Missile Pressure:
Initial Rate (Breakdown):
Dart/Ball Early :
CD4-587 - Narwal - Interval 17
Interval Summary
Average pH:
ISDP:
Proppant Summary
Average Rate:
Final 5 min:
Proppant in Formation:
Conoco Phillips - CD4-587 Interval Summary 30
CustomerFormationLeaseAPIDateWell SummaryWanli 20/40 Ceramic 100M Total Proppantrface Press Rate Visc Temp pHrface Press Rate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs13364 23.8 27 72.9 8.5 4012 25.7 2,202 28,651 682 630 15 121,785 2,900 145,730 5,736 151,466 23296 24.5 27 76 8.5 3670 25.7 1,592 66,879 1,592 145,029 5,487 150,516 33019 24.3 27 72 8.3 3666 25.7 1,386 58,218 1,386 149,778 6,018 155,796 43371 24.9 27 74 8.5 3780 25.9 1,282 12,674 302 66,523 1,584 148,647 5,467 154,114 52789 21.5 27 74 8.4 4162 26.1 1,328 3,217 77 756 18 59,764 1,423 131,828 5,350 137,178 63392 24.0 26 74 8.4 3874 25.8 1,000 42,006 1,000 129,890 3,901 133,791 73372 23.0 26 74 8.4 3756 25.7 1,029 43,231 1,029 130,524 4,166 134,690 83293 24.8 26 73 8.4 3704 25.9 841 11,705 279 47,020 1,120 130,808 3,586 134,394 92974 24.7 26 75 8.4 3408 26.3 1,117 4,954 118 1,344 32 53,193 1,267 131,001 4,098 135,099 103105 24.3 25 77 8.5 3555 26.1 964 40,506 964 130,643 4,534 135,177 113158 24.1 25 76 8.6 3723 26.1 812 34,093 812 126,391 3,770 130,161 123064 24.2 26 76 8.5 3484 26.1 821 34,486 821 132,406 4,557 136,963 133000 25.2 27 75 8.5 3283 26.2 769 10,974 261 43,264 1,030 131,788 4,562 136,350 142676 24.1 26 72 8.5 3351 26.0 972 2,106 50 4,200 100 47,135 1,122 130,012 2,981 132,993 153533 15.2 25 70 8.5 4265 15.9 1,046 14,072 335 58,014 1,381 68,588 4,802 73,390 163077 24.3 25 78 8.5 3590 26.0 1,104 46,361 1,104 132,917 3,400 136,317 172009 12.3 25 74 8.4 2334 12.3 10,066 240 10,066 240 Minimum769 2106 50 630 15 10066 240 68588 2981 73390 Average1142 10935 260 1733 41 51326 1222 130999 4526 135525 Maximum2202 28651 682 4200 100 121785 2900 149778 6018 155796 Wanli 20/40 Ceramic 100M Total ProppantPressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned16,871 87,208 2,076 0 0 4,520 108 800,308 19,055 2,261,000 72,000 2,234,610Recorded3183 24.0 26 75 8.45 4265 26.3 18,267 98,419 2,343 0 0 6,930 165 872,544 20,775 2,095,980 72,415 2,168,395Weight Tickets2,283,600 69,000 2,352,600** Proppant is billed from Weight Ticket volumesJanuary 19, 202450-103-20867CD4-587NarwalConoco Phillips IntervalAverage MaxSeawaterAverage MaxSeawater30# Delta Frac 30# Linear30# Delta Frac 30# Linear** IFS numbers for proppant are taken from software calculations based on Total FluidFluidsProppantsFluidsProppantsTotal FluidFreeze ProtectFreeze ProtectX6A0TConoco Phillips - CD4-587 Fluid System-Proppant Summary31
Hydraulic Fracturing Fluid Product Component Information Disclosure
2024-01-19
Alaska
HARRISON BAY
50-103-20867
CONOCOPHILLIPS
CD4 587
-150.9874
70.2923
NAD83
none
Oil
4209
865614
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%76.03117%7375032 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
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%0.00101%98
2,7-Naphthalenedisulfonic acid, 3-
hydroxy-4-[(4-sulfor-1-
naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00004%4
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00134%130
C.I. Pigment Red 5 6410-41-9 1.00%0.00019%19
Confidential Proprietary 10.00%0.00015%15 ResMetrics Product Stewardship
info@resmetri
cs.com 8325921900
Confidential Proprietary 100.00%0.00347%337 ResMetrics Product Stewardship
info@resmetri
cs.com 8325921900
Corundum 1302-74-5 65.00%14.83339%1438840
Crystalline silica, quartz 14808-60-7 100.00%0.71692%69542
Cured acrylic resin Proprietary 1.00%0.00019%19
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%0.06041%5860
Ethylene glycol 107-21-1 30.00%0.01141%1107
Glycol Ether Proprietary 85.00%0.00358%347 ResMetrics Product Stewardship
info@resmetri
cs.com 8325921900
Guar gum 9000-30-0 100.00%0.25794%25020
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.03020%2930
Hemicellulase 9025-56-3 5.00%0.00093%91
Monoethanolamine borate 26038-87-9 100.00%0.03802%3689
Mullite 1302-93-8 45.00%10.26927%996120
Naphthalene 91-20-3 5.00%0.00503%489
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.03020%2930 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxyalkylated phenolic resin Proprietary 10.00%0.01007%977 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%0.00503%489
Polyamine Proprietary 30.00%0.00558%542 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Propylene Glycol 57-55-6 20.00%0.00029%29
Sodium chloride 7647-14-5 5.00%3.80168%368764
Sodium hydroxide 1310-73-2 30.00%0.00360%350
Walnut hulls NA 100.00%0.01861%1805 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Water 7732-18-5 100.00%0.02458%2385
* 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
Allcomponentinformationlistedwasobtainedfromthesupplier’sMaterialSafetyDataSheets(MSDS).Assuch,theOperatorisnotresponsibleforinaccurateand/orincompleteinformation.AnyquestionsregardingthecontentoftheMSDSshouldbedirectedtothesupplier
whoprovidedit.TheOccupationalSafetyandHealthAdministration’s(OSHA)regulationsgovernthecriteriaforthedisclosureofthisinformation.PleasenotethatFederalLawprotects"proprietary","tradesecret",and"confidentialbusinessinformation"andthecriteriaforhow
thisinformationisreportedonanMSDSissubjectto29CFR1910.1200(i)andAppendixD.
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 CloseoutCD4-587Primary Job TypeINITIAL COMPLETIONStart Date1/10/2024End Date1/31/2024Final Job StatusIN PROGRESSTotal Time Log Hours (hr)310.64SummaryNetwork/Order NumberProject DescEstimator10455760 CD4-587 FracStart Date ZX Code Time Log Hrs (hr)Cum Time Log (days)Last 24hr Sum1/10/2024 ZX02 Fracturing 12.00 0.50 PREPPED TANK AREA, LAID AND SEAMED CONTAIMNET, RIGGED UP TANK FARM, PUT HEAT ON THE MANIFOLD1/11/2024 ZX02 Fracturing 17.99 1.25 TIED IN THE WATER DELIVERY MANIFOLD, DOUBLE TAPPED TANK MANIFOLD, LAID FRAC CONTAINMENT STOOD CASTLES, SPOTTED EQUIPMENT.1/12/2024 ZX02 Fracturing 23.99 2.25 LOADING PROPPANT, 9 BULKERS @ 52,000 LB LOADED INTO CASTLES,CONTINUED PRE LOADING PROPPANT @STAGINGSHUT DOWN FOR WEATHER1/13/2024 ZX02 Fracturing 23.99 3.25 WEATHER HOLD1/14/2024 ZX02 Fracturing 23.99 4.25 WEATHER HOLD UNTIL 6 AM, CREW THEN DISPATCHED TO START CLEARING SNOW FROM AROUND, AND IN EQUIPMENT, AFTERNOON BEGAN STARTING AND MOVING EQUIPMENT.THE PM CREWS STARTED LOADING PROPPANT AND FLOWING/HEATING SEAWATER1/15/2024 ZX02 Fracturing 23.99 5.25 FINISH LOADING & HEATNG WATER. CONTINUE CLEANING OUT SNOW & GET ALL EQUIPMENT RUNNING. RIGGED IN ALL 5 PUMPS TO MISSILE & RAN 4 IRON 1/3 OF THE WAY. RIGGED IN EPRV'S TO TANK. 1/16/2024 ZX02 Fracturing 23.99 6.25 4" IRON COMPLETE (590 FT) MISSLE TO GOATHEAD. FRONT YARD RIGGED UP. LOADED ACID PUMP WITH LVT & FUNCTION TESTED. NIGHT SHIFT RIGGED IN ACID PUMP. SPOT TCC & RAN PRESSURE CABLES. GNWF LAUNCHER & LAUNCH VALVES WERE RIGGED UP. FUNTION TEST BLENDER & ADP. 1/17/2024 ZX02 Fracturing 23.99 7.25 RIG UP ACID PUMP TO LAUNCH VALVES. WELL SUPPORT COMPLETE RIGGING UP IA & OA PRV's AND FLOWLINE TO TANKS. HALLIBURTON CREW SWAP. RU FRAC SHACK AUTO FUEL. LOAD GEL & CHEMICALS AND PREPARE EQUIPMENT TO PUMP TOMORROW. 1/18/2024 ZX02 Fracturing 23.99 8.25 DELAYED START DUE TO WAITING ON ESSENTIAL PERSONNEL TO ARRIVE IN ALPINE. ENCOUNTERED MULTIPLE ISSUES THROUGHOUT THE DAY & TIMED OUT TO START FRAC. HALLIBURTON PRESSURE TESTED FRAC LINES TO 8500 PSI **PASS** TO VERIFY NO LEAKS FOR RESTART IN THE MORNING. IN PROGRESS1/19/2024 ZX02 Fracturing 23.74 9.24 SHEAR ARSENAL DISC @ 5350 PSI. PUMP MINI FRAC & DETERMINE CLOSURE & FLUID EFFICIENCY. STIMULATE STAGES #1 - #4 PER DESIGN. RESMETRICS TRACER ADDED TO EACH STAGE PER SCHEDULE. TOTAL PROPPANT PUMPED = 611,892 LBS & TOTAL CLEAN VOL= 7446 BBLS.VISUALLY INSPECTED INTERRA SLEEVE **NO VISUAL SIGNS OF EROSION DETECTED** IN PROGRESS1/20/2024 ZX02 Fracturing 23.99 10.24 STIMULATE STAGES #5 - #8 PER DESIGN. RESMETRICS TRACER ADDED TO EACH STAGE PER SCHEDULE. TOTAL PROPPANT PUMPED = 540,053 LBS & TOTAL CLEAN VOL= 4554 BBLS. IN PROGRESS1/21/2024 ZX02 Fracturing 23.99 11.24 STIMULATE STAGES #9 - #13 PER DESIGN. RESMETRICS TRACER ADDED TO EACH STAGE PER SCHEDULE. TOTAL PROPPANT PUMPED = 673,751 LBS & TOTAL CLEAN VOL= 4862 BBLS. IN PROGRESS1/22/2024 ZX02 Fracturing 23.00 12.19 STIMULATE STAGE #14 PER DESIGN. RESMETRICS TRACER ADDED. LAUNCHED STAGE #15 PRIMARY DART. SEAT WAS NOT DEFINITIVE, DROP BACK UP DART THAT LANDED ON CORRECT DISPLACMENT VOL. STAGE #15 WAS SKIPPED DUE TO ABNORMAL TREATING PRESSURES.LAUNCH STAGE #16 DART & STIMULATE STAGE #16 PER DESIGN. RESMETRICS TRACER ADDED.DROPPED DART #17 TO OPEN SLEEVE 17 ONLY **NO PROPPANT PUMPED** RESMETETRIC TRACER WAS PUMPED IN THIS SLEEVE. TOTAL PROPPANT PUMPED = 342,939 LBS & TOTAL CLEAN VOL= 3747 BBLS. TOTAL AU DARTS DROPPED WAS 17 SMART DARTS & 1 MECHANICAL DART. FRAC COMPLETE. BEGIN RIG DOWN OPERATIONS. 1/23/2024 ZX02 Fracturing 6.00 12.44 RIG DOWN GNWF EQUIPMENT FROM WELLHEAD, ACID PUMP, DOWN JOINT & FRONT YARD. WELL SUPPORT RIG DOWN BALL LAUNCH LINE, IA & OA POP OFF LINES. IN PROGRESS1/24/2024 ZX02 Fracturing 12.00 12.94 RIG DOWN PUMPS, MISSILE, BLENDER & ADP. BREAK DOWN THE REST OF THE 4" HARDLINE. TRIP EQUIPMENT TO MT6. JOB COMPLETE
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: 4705' FSL, 4032' FEL S28 T11N R5E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 19.1 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 79'
13-3/8 L-80 2398'
9-5/8" T-95 3454'
7-5/8" L-80 4068'
4 1/2" P11OS 4192'
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
None
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 (12/19/2023): 13200'MD/4023'TVD - 20492'MD/4192'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
55'
0
Per 20 AAC 25.283 (i)(2) attach electronic information
47
13597'
51'
3431'
94
68
79'
51' 9356'
SIZE DEPTH SET (MD)
10 Yards
PACKER SET (MD/TVD)
13200'
42"
12.6
5957584
ADL384211, ADL380082, ADL380081
LONS 97-007
55'
29.7
0
9207'
2865'
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
389697
393102
CEMENTING RECORD
5954376
1278'MD/1264'TVD
SETTING DEPTH TVD
5948431
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER, Mud
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
12/28/2023 223-098
50-103-20867-00-00
CRU CD4-587
11/22/2023
20669'MD/4195'TVD
N/A
73.7
P.O.Box 100360, Anchorage, AK 99510-0360
378426
2459' FSL, 4781' FEL S19 T11N R5E
4090' FSL, 555' FEL S33 T11N R5E
12/16/2023
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,
131ppg 15.8ppg Class G8.5"x9 .5"
TUBING RECORD
20492'
165ppg 15.8ppg Class G
4023'
12-1/4"
6.5"
13206'4.5 13070'MD/4007' TVD
13212'MD/4024' TVD
BOTTOM
16" Lead:409bbls 11.0ppg Class G
Tail:73bbls 15.8ppg Class G
CASING
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
Colville River Field/ Qannik Oil Pool
By Grace Christianson at 9:54 am, Jan 25, 2024
Completed
12/28/2023
JSB
RBDMS JSB 020124
DSR-2/13/24 G
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1278 1264
C-40 2475 2217
2997 2457
4187 2768
C-10 6035 3024
K3 12011 3855
13809 4092
20669 4195
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: Matt Nagel
Digital Signature with Date:
Contact Phone:907-263-4747
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:matt.b.nagel@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
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag / Drift: New well CD4-587 1/1/2024 oberr
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Frac CD4-587 1/22/2024 claytg
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
Conductor 20 19.12 0.0 79.0 79.0 94.00 X65
Surface 13 3/8 12.42 54.6 2,864.6 2,398.2 68.00 L80 HYD563
Intermediate 1 9 5/8 8.68 51.4 9,355.7 3,453.7 47.00 T95 H563
Intermediate 2 7 5/8 6.88 9,207.3 13,597.4 4,067.8 29.70 L-80 TSH 523
Liner 4 1/2 3.96 13,200.0 20,492.0 4,191.9 12.60 P-110 HYD 563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
49.7
Set Depth …
13,206.0
String Max No…
4 1/2
Set Depth …
4,023.7
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
49.7 49.7 0.00 Hanger 13.625 FMC 4-1/2" Tubing Hanger Hydril
HYD 563 Min ID 3.92"
FMC TC-1A-
EMS
3.900
1,544.9 1,513.6 24.05 Nipple - DB,
XN, DS, D
4.500 NIPPLE,LANDING,4 1/2","X",3.813",
H563
HES X Nipple 3.813
3,180.3 2,516.1 68.38 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM w/ DCK-2
SOV @ 2K, 12.6# H563 BEK Latch
Camco KBG4-5 3.865
9,110.5 3,417.0 81.66 Mandrel 4.500 GLM, Silverwell Smart w/ DHG 4-
1/2, 12.6#, L-80, Vam Top
Silverwel
l
3.898
12,935.7 3,988.9 81.74 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM w/ Dummy
Valve, 12.6# H563 BK Latch
Camco KBG4-5 3.865
13,003.8 3,998.3 82.46 Sleeve - Sliding 4.500 Sliding Sleeve, CMU, 4.5" x 3.813"
GX profile, Vam Top, Up to open
Baker Nexo-2 3.813
13,136.2 4,015.3 82.85 Nipple - DB,
XN, DS, D
4.500 NIPPLE,LANDING,4
1/2","DB",3.750", H563
SLB DB-6
nipple
3.750
13,189.3 4,021.8 83.10 Sub - Shear
Out - SOS
5.750 Arsenal glass plug, 5500 psi, 4-1/2,
4140, H563
Arsenal 5.5K 3.910
13,197.1 4,022.7 83.13 Locator 5.640 Locator No Go (6.38" OD) Baker 3.880
13,202.7 4,023.4 83.15 Shoe - Mule 4.500 HES 3.910
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
3,180.3 2,516.1 68.38 1 GAS LIFT DMY BK 4 1/2 0.0 1/10/2024 Camco KBG4-5 0.000
9,110.5 3,417.0 81.66 2 GAS LIFT Smart
GLM /
DHG
4 1/2 0.0 12/23/2023 SilverW
ell
12,935.7 3,988.9 81.74 3 GAS LIFT DMY BK 4 1/2 0.0 12/23/2023 Camco KBG4-5 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
13,211.9 4,024.4 83.18 Packer 6.400 Baker SLZXP (HRD-E) Packer SLZXP
LTP
4.790
13,220.3 4,025.4 83.21 Nipple - RS 5.500 Baker RS Nipple R/S
Nipple
4.250
13,222.6 4,025.7 83.22 XO Reducing 5.500 Crossover 5-1/2" H563 pin x 4-
1/2" 12.6# H563 pin, 110 MYS
material
XO 3.910
13,638.9 4,073.6 82.33 Packer - Swell 4.500 Baker Oil Swell Packer #17, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.960
14,278.5 4,132.9 86.22 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#17, 4-1/2" 12.6# C110 HYD563
**OPENED 1/22/24**
Advance
d
Upstrea
m
107343-
000100
3.505
14,485.3 4,138.1 90.75 Packer - Swell 4.500 Baker Oil Swell Packer #16, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.930
14,671.7 4,134.1 91.32 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#16, 4-1/2" 12.6# C110 HYD563
**OPENED 1/22/24**
Advance
d
Upstrea
m
107343-
000058
3.505
14,839.6 4,130.3 91.32 Packer - Swell 4.500 Baker Oil Swell Packer #15, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.970
15,025.8 4,125.8 91.44 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#15, 4-1/2" 12.6# C110 HYD563
**OPENED 1/22/24**
Advance
d
Upstrea
m
107343-
000057
3.505
15,193.7 4,120.8 91.88 Packer - Swell 4.500 Baker Oil Swell Packer #14, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.880
15,380.8 4,116.5 90.39 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#14, 4-1/2" 12.6# C110 HYD563
**OPENED 1/22/24**
Advance
d
Upstrea
m
107343-
000054
3.505
HORIZONTAL, CD4-587, 1/24/2024 7:41:16 AM
Vertical schematic (actual)
Liner; 13,200.0-20,492.0
Hydraulic fracture; 20,107.0
Hydraulic fracture; 19,733.0
Hydraulic fracture; 19,345.0
Hydraulic fracture; 18,950.0
Hydraulic fracture; 18,517.0
Hydraulic fracture; 18,166.0
Hydraulic fracture; 17,773.0
Hydraulic fracture; 17,378.0
Hydraulic fracture; 17,025.0
Hydraulic fracture; 16,631.0
Hydraulic fracture; 16,277.0
Hydraulic fracture; 15,923.0
Hydraulic fracture; 15,568.0
Hydraulic fracture; 15,214.0
Hydraulic fracture; 14,859.0
Hydraulic fracture; 14,508.0
Intermediate 2; 9,207.3-13,597.4
Sub - Shear Out - SOS;
13,189.3
Nipple - DB, XN, DS, D;
13,136.2
Packer (Tubing); 13,069.9
Sleeve - Sliding; 13,003.8
Mandrel; 12,935.7
Intermediate String 2 Cement;
10,504.0 ftKB
Intermediate 1; 51.4-9,355.7
Mandrel; 9,110.5
Intermediate String 1 Cement;
7,329.0 ftKB
Mandrel; 3,180.3
Surface; 54.6-2,864.6
Nipple - DB, XN, DS, D; 1,544.9
Stage Cementing; 54.6 ftKB
Conductor; 0.0-79.0
Hanger; 49.7
WNS PROD
KB-Grd (ft)
54.60
RR Date
12/28/202
3
Other Elev…
CD4-587
...
TD
Act Btm (ftKB)
20,669.0
Well Attributes
Field Name
NARWHAL
Wellbore API/UWI
501032086700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
91.90
MD (ftKB)
15,147.73
WELLNAME WELLBORECD4-587
Annotation End DateH2S (ppm) DateComment
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
15,548.8 4,118.0 88.83 Packer - Swell 4.500 Baker Oil Swell Packer #13, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.890
15,734.5 4,122.6 88.12 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#13, 4-1/2" 12.6# C110 HYD563
**OPENED 1/21/24**
Advance
d
Upstrea
m
107343-
000052
3.505
15,902.2 4,128.8 87.78 Packer - Swell 4.500 Baker Oil Swell Packer #12, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.890
16,089.2 4,134.8 88.83 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#12, 4-1/2" 12.6# C110 HYD563
**OPENED 1/21/24**
Advance
d
Upstrea
m
107343-
000051
3.505
16,256.9 4,138.3 88.78 Packer - Swell 4.500 Baker Oil Swell Packer #11, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.890
16,443.4 4,141.9 89.16 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#11, 4-1/2" 12.6# C110 HYD563
**OPENED 1/21/24**
Advance
d
Upstrea
m
107343-
000048
3.505
16,611.4 4,144.2 89.28 Packer - Swell 4.500 Baker Oil Swell Packer #10, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below))
Baker H30192045
3
3.890
16,797.1 4,145.5 89.50 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#10, 4-1/2" 12.6# C110 HYD563
**OPENED 1/21/24**
Advance
d
Upstrea
m
107343-
000047
3.505
17,006.2 4,149.4 88.56 Packer - Swell 4.500 Baker Oil Swell Packer #9, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.890
17,191.2 4,156.5 87.42 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#9, 4-1/2" 12.6# C110 HYD563
**OPENED 1/21/24**
Advance
d
Upstrea
m
107343-
000045
3.505
17,358.1 4,164.0 87.46 Packer - Swell 4.500 Baker Oil Swell Packer #8, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.890
17,544.0 4,170.7 88.65 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#8, 4-1/2" 12.6# C110 HYD563
**OPENED 1/21/24**
Advance
d
Upstrea
m
107343-
000027
3.505
17,752.9 4,172.1 90.64 Packer - Swell 4.500 Baker Oil Swell Packer #7, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) ( needs
6.125 joint below)
Baker H30192045
3
3.890
17,939.4 4,169.1 90.98 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#7, 4-1/2" 12.6# C110 HYD563
**OPENED 1/20/24**
Advance
d
Upstrea
m
107343-
000024
3.505
18,146.4 4,166.0 90.32 Packer - Swell 4.500 Baker Oil Swell Packer #6, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.890
18,329.5 4,166.8 89.39 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#6, 4-1/2" 12.6# C110 HYD563
**OPENED 1/20/24**
Advance
d
Upstrea
m
107343-
000022
3.505
18,497.1 4,168.5 89.43 Packer - Swell 4.500 Baker Oil Swell Packer #5, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.860
18,724.9 4,169.8 89.71 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#5, 4-1/2" 12.6# C110 HYD563
**OPENED 1/20/24**
Advance
d
Upstrea
m
107343-
000012
3.505
18,930.1 4,171.6 88.84 Packer - Swell 4.500 Baker Oil Swell Packer #4, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) ( needs
6.125 joint below)
Baker H30192045
3
3.860
19,116.2 4,175.9 88.39 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#4, 4-1/2" 12.6# C110 HYD563
**OPENED 1/19/24**
Advance
d
Upstrea
m
107343-
000009
3.505
19,324.8 4,182.6 88.16 Packer - Swell 4.500 Baker Oil Swell Packer #3, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.880
19,508.2 4,188.1 88.58 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#3, 4-1/2" 12.6# C110 HYD563
**OPENED 1/19/24**
Advance
d
Upstrea
m
107343-
000004
3.505
19,712.8 4,190.2 90.02 Packer - Swell 4.500 Baker Oil Swell Packer #2, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.890
19,898.9 4,189.2 90.58 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#2, 4-1/2" 12.6# C110 HYD563
**OPENED 1/19/24**
Advance
d
Upstrea
m
107343-
000003
3.505
20,108.0 4,188.0 89.63 Packer - Swell 4.500 Baker Oil Swell Packer #1, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 6.125) (needs
6.125 Cent joint below)
Baker H30192045
3
3.860
HORIZONTAL, CD4-587, 1/24/2024 7:41:16 AM
Vertical schematic (actual)
Liner; 13,200.0-20,492.0
Hydraulic fracture; 20,107.0
Hydraulic fracture; 19,733.0
Hydraulic fracture; 19,345.0
Hydraulic fracture; 18,950.0
Hydraulic fracture; 18,517.0
Hydraulic fracture; 18,166.0
Hydraulic fracture; 17,773.0
Hydraulic fracture; 17,378.0
Hydraulic fracture; 17,025.0
Hydraulic fracture; 16,631.0
Hydraulic fracture; 16,277.0
Hydraulic fracture; 15,923.0
Hydraulic fracture; 15,568.0
Hydraulic fracture; 15,214.0
Hydraulic fracture; 14,859.0
Hydraulic fracture; 14,508.0
Intermediate 2; 9,207.3-13,597.4
Sub - Shear Out - SOS;
13,189.3
Nipple - DB, XN, DS, D;
13,136.2
Packer (Tubing); 13,069.9
Sleeve - Sliding; 13,003.8
Mandrel; 12,935.7
Intermediate String 2 Cement;
10,504.0 ftKB
Intermediate 1; 51.4-9,355.7
Mandrel; 9,110.5
Intermediate String 1 Cement;
7,329.0 ftKB
Mandrel; 3,180.3
Surface; 54.6-2,864.6
Nipple - DB, XN, DS, D; 1,544.9
Stage Cementing; 54.6 ftKB
Conductor; 0.0-79.0
Hanger; 49.7
WNS PROD CD4-587
...
WELLNAME WELLBORECD4-587
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
20,293.5 4,189.7 89.49 Sleeve - Frac 4.500 Advanced Upstream frac sleeve
#1, 4-1/2" 12.6# C110 HYD563
**OPENED 1/19/24**
Advance
d
Upstrea
m
107343-
000002
3.950
20,305.4 4,189.8 89.48 Sleeve - Frac 4.500 Baker Alpha Pressure Sleeve, 4
1/2", 13.5#, 125 MYS, H563, #11
disc
Baker Alpha P
Sleeve
2.990
20,309.1 4,189.8 89.48 Valve 4.500 Wellbore Isolation Sleeve, 4 1/2",
13.5#, P110, H563
Baker WIV 3.875
HORIZONTAL, CD4-587, 1/24/2024 7:41:16 AM
Vertical schematic (actual)
Liner; 13,200.0-20,492.0
Hydraulic fracture; 20,107.0
Hydraulic fracture; 19,733.0
Hydraulic fracture; 19,345.0
Hydraulic fracture; 18,950.0
Hydraulic fracture; 18,517.0
Hydraulic fracture; 18,166.0
Hydraulic fracture; 17,773.0
Hydraulic fracture; 17,378.0
Hydraulic fracture; 17,025.0
Hydraulic fracture; 16,631.0
Hydraulic fracture; 16,277.0
Hydraulic fracture; 15,923.0
Hydraulic fracture; 15,568.0
Hydraulic fracture; 15,214.0
Hydraulic fracture; 14,859.0
Hydraulic fracture; 14,508.0
Intermediate 2; 9,207.3-13,597.4
Sub - Shear Out - SOS;
13,189.3
Nipple - DB, XN, DS, D;
13,136.2
Packer (Tubing); 13,069.9
Sleeve - Sliding; 13,003.8
Mandrel; 12,935.7
Intermediate String 2 Cement;
10,504.0 ftKB
Intermediate 1; 51.4-9,355.7
Mandrel; 9,110.5
Intermediate String 1 Cement;
7,329.0 ftKB
Mandrel; 3,180.3
Surface; 54.6-2,864.6
Nipple - DB, XN, DS, D; 1,544.9
Stage Cementing; 54.6 ftKB
Conductor; 0.0-79.0
Hanger; 49.7
WNS PROD CD4-587
...
WELLNAME WELLBORECD4-587
Page 1/37
CD4-587
Report Printed: 1/24/2024
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
18:00
11/19/2023
20:00
2.00 MIRU, MOVE MOB P Continue disconnect inter connects and
prepare pipe shed to move.
0.0 0.0
11/19/2023
20:00
11/20/2023
00:00
4.00 MIRU, MOVE MOB P Disconnect modules, pull pipe shed
away from sub,and move around well
rows spot near CD4-587. Continue to
prep modules for move.
0.0 0.0
11/20/2023
00:00
11/20/2023
07:00
7.00 MIRU, MOVE MOB P Finish spotting rig matting around CD4-
587.
Move sub base and spot near CD4-587
Finish cleaning up CD4-536 for
handover to production.
0.0 0.0
11/20/2023
07:00
11/20/2023
15:30
8.50 MIRU, MOVE MOB P Move BOP Module and spot over CD4-
587
Move motor and pump complex around
well row and spot near CD4-587.
0.0 0.0
11/20/2023
15:30
11/20/2023
22:00
6.50 MIRU, MOVE MOB P Move CPU to around well row to 587
area.
Spot and connect Sub base to BOP
module.
0.0 0.0
11/20/2023
22:00
11/21/2023
00:00
2.00 MIRU, MOVE MOB P Continue spot and shim sub base to
BOP module.
0.0 0.0
11/21/2023
00:00
11/21/2023
06:00
6.00 MIRU, MOVE MOB P Skid rig floor from Sub to BOP module,
spot pit module with truck and stomp pit
module into place, spot pump module
with truck and stomp into place, stomp
CPU into place. Stomp and stage pipe
shed to sub. Spot motor complex.
0.0 0.0
11/21/2023
06:00
11/21/2023
12:00
6.00 MIRU, MOVE MOB P Stomp pipe shed office into place.
position motor room with truck and
stomp into place. Hook up interconnects
between modules. Plug in all wires
between modules, work on rig
acceptance check lists.
0.0 0.0
11/21/2023
12:00
11/21/2023
15:00
3.00 MIRU, MOVE MOB P Turn on steam to rig, install CPU Chute
adapter. Test drawworks , top drive and
skate, remove RT plug and install boot
protector, finish rig acceptance checklist.
0.0 0.0
11/21/2023
15:00
11/21/2023
16:00
1.00 MIRU, MOVE MOB P Install mouse hole, install Fox hole, pull
mouse hole and lay on skate. gather
RKB's.
RKB - LR = 54.59
RKB - GL = 54.63
0.0 0.0
11/21/2023
16:00
11/21/2023
18:00
2.00 MIRU, MOVE RURD P FMC rep install landing ring, install
conductor adapter and riser as per
FMC. Mobilize ST-120 to rig floor and
install. Load 84 joints of 5-7/8 drillpipe in
pipeshed.
Connect rig to High line power and
initiate at 14:30 hrs.
0.0 0.0
11/21/2023
18:00
11/22/2023
00:00
6.00 MIRU, MOVE RURD P Install conductor adapter as per FMC
rep, continue assembly of ST120's on
rig floor. Install low pressure riser with
new gasket. Inspect air boots install
upper low pressure riser. Install mouse
hole, SIMOPS MP2's and inspect pit
equipment, prepare pits for spud.
0.0 0.0
11/22/2023
00:00
11/22/2023
01:30
1.50 MIRU, MOVE RURD P R/U floor for stand building 5-7/8"
drillpipe. Install 4 point tie downs to low
pressure riser in BOP deck. continue
prepping pits for spud. Continue
installing CPU auger chute. Perform
derrick inspection.
0.0 0.0
11/22/2023
01:30
11/22/2023
02:15
0.75 MIRU, MOVE SFTY P Large amounts of ice found in derrick,
clear rig floor and proccede to remove
ice from Derrick before P/U drill pipe.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 2/37
CD4-587
Report Printed: 1/24/2024
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)
11/22/2023
02:15
11/22/2023
08:00
5.75 MIRU, MOVE PULD P M/U first stand and RIH tag ice at 63
feet.
Pick up 84 joints 5-7/8" of drillpipe from
pipe shed and build 28 stands rack back
in derrick.
Make up and rack back stand of HWDP
and 2 NMDC.
0.0 0.0
11/22/2023
08:00
11/22/2023
08:30
0.50 MIRU, MOVE CLEN P Clean and clear rig floor prep for slip
and cut.
0.0 0.0
11/22/2023
08:30
11/22/2023
13:15
4.75 MIRU, MOVE SLPC P Slip and cut 10 wraps of drilling line.
Adjust brakes and service top drive and
blocks.
Un Hang blocks and calibrate empty
block weight.
0.0 0.0
11/22/2023
13:15
11/22/2023
15:00
1.75 MIRU, MOVE SEQP P P/U stand of 5-7/8" DP drop double joint
in mouse hole and M/U top drive to
single joint for filling riser.
Flood riser with mud and pressure test
stand pipe to 3500 psi.
0.0 0.0
11/22/2023
15:00
11/22/2023
16:00
1.00 MIRU, MOVE RURD P Blow down top drive, rack back stand of
5-7/8". mobilize bit breaker to floor prep
dog collars and slips.
0.0 0.0
11/22/2023
16:00
11/22/2023
17:30
1.50 MIRU, MOVE BHAH P P/U BHA #1 to 47' P/U NMDC's and and
wash down tag with 5K at 65'
0.0 65.0
11/22/2023
17:30
11/22/2023
18:30
1.00 MIRU, MOVE REAM P Continue clean out conductor fom 65'
MD to 133' MD at
400 GPM
315 PSI
40 RPM
2-5K WOB
0 TQ
65.0 133.0
11/22/2023
18:30
11/22/2023
20:00
1.50 SURFAC, DRILL BHAH P M/U MWD tools in BHA as per SLB DD. 133.0 133.0
11/22/2023
20:00
11/23/2023
00:00
4.00 SURFAC, DRILL DDRL P Drill ahead 16" surface hole section.
from 133' MD to 461' MD.
620 gpm; 789 psi
40 rpm; Tq on 2K, off 1K
WOB 4-6K
PUW 175K
SOW 98K
RTW 96K
ECD 11.09
133.0 461.0
11/23/2023
00:00
11/23/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill ahead 16" surface hole section.
from 461' MD to 1,043' MD. Pump 40
bbls anti-bit balling fine nut plug / drill
zone sweeps every other stand.
650gpm; 1106 psi
40 rpm; Tq on 6K, off 2K
WOB 17K
PUW 116K
SOW 121K
RTW 114K
ECD 11.29
461.0 1,043.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 3/37
CD4-587
Report Printed: 1/24/2024
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)
11/23/2023
06:00
11/23/2023
12:00
6.00 SURFAC, DRILL DDRL P Drill ahead 16" surface hole section.
from 1,043' MD to 1,780' MD. Pump 40
bbls anti-bit balling fine nut plug / drill
zone sweeps every other stand.
900 gpm; 1800 psi
50 rpm; Tq on 4-8K, off 3K
WOB 3-25K
PUW 140K
SOW 125K
RTW 135K
ECD 11.98
1,043.0 1,780.0
11/23/2023
12:00
11/23/2023
18:00
6.00 SURFAC, DRILL DRLG P Drill ahead 16" surface hole section.
from 1,780' MD to 2,342' MD. Pump 40
bbls anti-bit balling fine nut plug / drill
zone sweeps every other stand.
1000 gpm; 2100 psi
60 rpm; Tq on 4-8K, off 3K
WOB 5-40K
PUW 150K
SOW 135K
RTW 140K
ECD 11.02
1,780.0 2,342.0
11/23/2023
18:00
11/24/2023
00:00
6.00 SURFAC, DRILL DRLG P Drill ahead 16" surface hole section.
from 2,342' MD to 2,782' MD. Pump 40
bbls anti-bit balling fine nut plug / drill
zone sweeps every other stand.
1100 gpm; 2782 psi
60 rpm; Tq on 4-8K, off 3K
WOB 21-30K
PUW 156K
SOW 138K
RTW 141K
ECD 11.27
2,342.0 2,782.0
11/24/2023
00:00
11/24/2023
01:15
1.25 SURFAC, DRILL DDRL P Drill ahead 16" surface hole section.
from 2,782' MD to section TD at 2,872'
MD. Pump 40 bbls anti-bit balling fine
nut plug / drill zone sweeps every other
stand.
1100 gpm; 2782 psi
60 rpm; Tq on 4-8K, off 3K
WOB 21-30K
PUW 156K
SOW 138K
RTW 141K
ECD 11.27
2,782.0 2,872.0
11/24/2023
01:15
11/24/2023
02:45
1.50 SURFAC, TRIPCAS BKRM P Pump 40 bbl anti-bit balling sweep,
BROOH F/2,872 T/2,709 while
circulating bottoms up per stand.
1100 gpm; 2409 psi
80 rpm; Tq 6K
2,872.0 2,709.0
11/24/2023
02:45
11/24/2023
03:30
0.75 SURFAC, TRIPCAS OWFF P OWFF for 30 min - static. SIMOPS
prepare for BROOH operations.
2,709.0 2,709.0
11/24/2023
03:30
11/24/2023
06:00
2.50 SURFAC, TRIPCAS BKRM P BROOH 400-600 FPH staging up pulling
speed F/2,709' T/2,195'. Monitor hole fill
on active pit.
1100 gpm; 2346 psi
80 rpm; Tq 6K
2,709.0 2,195.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 4/37
CD4-587
Report Printed: 1/24/2024
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)
11/24/2023
06:00
11/24/2023
10:45
4.75 SURFAC, TRIPCAS BKRM P BROOH 400-600 FPH staging up pulling
speed F/2,195' T/1,328'. Monitor hole fill
on active pit.
1100 gpm; 2200 psi
80 rpm; Tq 4-10K
RTW 123
2,195.0 1,328.0
11/24/2023
10:45
11/24/2023
12:00
1.25 SURFAC, TRIPCAS PMPO P Orient motor to high side and pump
OOH F/1,328' T/1,118'.
250 gpm, 300 psi.
P/U 130k
1,328.0 1,118.0
11/24/2023
12:00
11/24/2023
14:30
2.50 SURFAC, TRIPCAS PMPO P Pump OOH F/1,118 T/485'. Spot gel pill
from 900' to BHA.
250 gpm, 300 psi
1,118.0 485.0
11/24/2023
14:30
11/24/2023
14:45
0.25 SURFAC, TRIPCAS OWFF P OWFF. PJSM on l/d BHA. 485.0 485.0
11/24/2023
14:45
11/24/2023
16:15
1.50 SURFAC, TRIPCAS PMPO P Pump HWDP OOH F/485' T/207'
spotting gell pill. Blow down top drive.
84 gpm, 100 psi.
485.0 207.0
11/24/2023
16:15
11/24/2023
19:15
3.00 SURFAC, TRIPCAS BHAH P L/D BHA F/207' to surface. Monitor hole
fill on active.
207.0 0.0
11/24/2023
19:15
11/24/2023
19:45
0.50 SURFAC, CASING CLEN P Clean and clear rig floor. 0.0 0.0
11/24/2023
19:45
11/24/2023
21:30
1.75 SURFAC, CASING RURD P Mobilize casing equipment to rig floor.
M/U Volant CRT as per Casing rep,
install bail extensions and casing
elevators. Install spider and secure to
rotary.
0.0 0.0
11/24/2023
21:30
11/25/2023
00:00
2.50 SURFAC, CASING PUTB P PJSM, RIH with 13-3/8", 68#, L80, H563
casing to 410' MD as per casing tally.
Backer-loc shoe track joints to pin of Jt
#4. Checked floats ok. Torque shoe
track to 30K, all others to 25K and
double bumped. Filling casing on the fly.
Monitor displacement on isolated pit #5.
0.0 410.0
11/25/2023
00:00
11/25/2023
02:15
2.25 SURFAC, CASING PUTB P RIH with 13-3/8", 68#, L80, H563 casing
F/410' T/1,280' as per casing tally.
Torque to 25K and double bumped.
Filling casing on the fly and top off every
10 joints. Monitor displacement on
isolated pit #5.
S/O 140K
410.0 1,280.0
11/25/2023
02:15
11/25/2023
03:00
0.75 SURFAC, CASING CIRC P Establish circulation and stage up to 8
bpm. Circulated b/u at 8 bpm with full
returns at base of permafrost. Minimal
clay cuttings observed at shakers while
circulating.
1,280.0 1,280.0
11/25/2023
03:00
11/25/2023
07:30
4.50 SURFAC, CASING PUTB P RIH with 13-3/8", 68#, L80, H563 casing
F/1,280' T/2,820' as per casing tally.
Torque to 25K and double bumped.
Filling casing on the fly and top off every
10 joints. Monitor displacement on
isolated pit #5.
S/O 140K
1,280.0 2,820.0
11/25/2023
07:30
11/25/2023
08:15
0.75 SURFAC, CASING PUTB P MU FMC hanger and 13-3/8" landing
joints per FMC rep. Precautionary wash
down at .05 bpm w/40 psi and land on
hanger with shoe at 2,864' MD.
S/O.186K
2,820.0 2,864.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 5/37
CD4-587
Report Printed: 1/24/2024
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)
11/25/2023
08:15
11/25/2023
09:30
1.25 SURFAC, CEMENT CIRC P Circ and condition mud for cementing.
Stage up pump rate to 8 BPM, 155 PSI.
Circulated bottoms up with full returns.
2,864.0 2,864.0
11/25/2023
09:30
11/25/2023
10:00
0.50 SURFAC, CEMENT RURD P Blow down top drive. R/U cement lines
on CRT.
2,864.0 2,864.0
11/25/2023
10:00
11/25/2023
12:00
2.00 SURFAC, CEMENT CIRC P Stage pump to 8 bpm, 410 psi and
circulate with full returns through cement
line while preparing pits / cpu for cement
job. PJSM.
2,864.0 2,864.0
11/25/2023
12:00
11/25/2023
13:15
1.25 SURFAC, CEMENT CMNT P Pressure test lines to 4188 psi.
Pumped 100 bbls 10.8 ppg mud push at
4.4 bpm at 160 psi. Loaded bottom plug,
broke rupture disk when attempting to
push wiper plug into casing.
2,864.0 2,864.0
11/25/2023
13:15
11/25/2023
14:00
0.75 SURFAC, CEMENT CMNT T Blow down cement line to unit. Wait on
replacement bottom wiper plug to arrive.
2,864.0 2,864.0
11/25/2023
14:00
11/25/2023
17:15
3.25 SURFAC, CEMENT CMNT P Load replacement bottom plug. SLB mix
and pump 409 bbls of 11.0 ppg lead
cement at 5.2 BPM, 238 psi, mix and
pump 73.7 bbls 15.8 ppg tail cement at
5.2 bpm, 241 PSI, drop top plug, kick
out with 20 bbls water, swap to rig pump
and displace cement with 397 bbls 10.5
ppg mud. Bump plug with 3346 stks with
500 psi over FCP to 1100 psi. Held 5
min, check floats ok, no losses
throughout job. CIP at 17:13 hrs on 25
Nov 2023.
Note: Cement at surface at 40 bbls (340
stks) into displacement and at 78 bbls
(660 stks) had 11.0 ppg cement back.
Total cement to surface 218 bbls.
Observed pack off at 115.6 bbls (974
stks) into displacement, slowed to 3
bpm. Picked up string off landing ring 6"
and regained full circulation. Re Landed
casing hanger and increased back to 6
bpm on displacement with no further
issues.
2,864.0 2,864.0
11/25/2023
17:15
11/25/2023
17:30
0.25 SURFAC, CEMENT CMNT P Held 1100 psi for 5 minutes. Bled off
pressure and checked floats - holding.
Blow down cement line.
2,864.0 2,864.0
11/25/2023
17:30
11/25/2023
18:30
1.00 SURFAC, CEMENT RURD P Drain riser and back out landing joints.
L/D landing joints as per FMC rep.
2,864.0 2,864.0
11/25/2023
18:30
11/25/2023
20:00
1.50 SURFAC, CEMENT RURD P R/D casing elevators and bail
extensions. R/D CRT as per DD Casing
rep.
2,864.0 2,864.0
11/25/2023
20:00
11/25/2023
20:45
0.75 SURFAC, CEMENT CLEN P Clean and clear rig floor of casing
equipment.
2,864.0 2,864.0
11/25/2023
20:45
11/25/2023
22:00
1.25 SURFAC, CEMENT WWWH P M/U stack washing tool on stand 5-7/8"
DP. Wash casing hanger area at 450
gpm while cleaning out flow box and
under rotary table. L/D stack washing
tool and rack back stand DP.
2,864.0 2,864.0
11/25/2023
22:00
11/25/2023
23:30
1.50 SURFAC, CEMENT WWWH P Drain riser, clean out conductor valves
and clean cellar box.
2,864.0 2,864.0
11/25/2023
23:30
11/26/2023
00:00
0.50 SURFAC, CEMENT NUND P N/D top section of surface riser. 2,864.0 2,864.0
11/26/2023
00:00
11/26/2023
01:00
1.00 SURFAC, CEMENT NUND P N/D middle and lower sections of
surface riser with surface adapter and
rack back on storage stump.
2,864.0 2,864.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 6/37
CD4-587
Report Printed: 1/24/2024
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)
11/26/2023
01:00
11/26/2023
02:30
1.50 SURFAC, WHDBOP NUND P Install and orient FMC wellhead as per
FMC procedures. Test wellhead seals to
1000 psi for 10 minutes - good test.
Witnessed by CPAI Co Rep.
2,864.0 2,864.0
11/26/2023
02:30
11/26/2023
06:00
3.50 SURFAC, WHDBOP NUND P N/U HP riser and 18-3/4" BOP and
torque flanges to spec. Install kill line
HCR valve (replacement) and kill line
shock hose.
2,864.0 2,864.0
11/26/2023
06:00
11/26/2023
09:45
3.75 SURFAC, WHDBOP NUND P Torque nuts on kill line and block. Install
koomey lines to kill HCR. Clean air
boots and install flow line riser. Install
MPD lines.
SIMOPS: Inspect and change out carrier
bearings (2) on auger. Service hammer
mill. Clean out flow line. Install second
annulus valve on annulus.
2,864.0 2,864.0
11/26/2023
09:45
11/26/2023
12:00
2.25 SURFAC, WHDBOP BOPE P Install test cap on top drive. M/U 5-7/8"
TIW and dart valve for testing. M/U 5-
7/8" test joint, pups and FMC test plug.
Flood BOP with water and purge lines.
Check for leaks.
2,864.0 2,864.0
11/26/2023
12:00
11/26/2023
14:30
2.50 SURFAC, WHDBOP BOPE P Shell test BOP's to 2500 psi. Test new
kill HCR and UPR's T/250 low, 5000
high while waiting on AOGCC rep to
arrive. Good test.
2,864.0 2,864.0
11/26/2023
14:30
11/26/2023
22:15
7.75 SURFAC, WHDBOP BOPE P Perform BOP test with 5-7/8" test joint
and charted all test. 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.
Note:Test pump leaking on test #9.
Troubleshoot and found bleeder needle
valve leaking.
#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 3075 psi; manifold
pressure 1450 psi; after all closures
1675 psi; 200 psi build with 2 electric
pumps in 11 seconds; full pressure
attained in 85 seconds. Closing times:
annular 15 seconds; UPR 14 seconds;
blind/shear 15 seconds; LPR 14
seconds; choke HCR 1 second; kill HCR
1 second. 10 bottles nitrogen backup
4000 psi avg. Gas detection system, pit
level indicators and flow alarms tested.
Test witnessed by AOGCC, Sean
Sullivan.
2,864.0 2,864.0
11/26/2023
22:15
11/26/2023
23:30
1.25 SURFAC, WHDBOP MPDA P M/U MPD test plug on jt 5-7/8" DP.
Install and verified clamped. Shell test
MPD equipment to 250 / 1300 psi for 5
minutes each. Charted test..
2,864.0 2,864.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 7/37
CD4-587
Report Printed: 1/24/2024
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)
11/26/2023
23:30
11/27/2023
00:00
0.50 SURFAC, WHDBOP BOPE P Pull BOP test plug as per FMC rep.
Drain BOP. Install 12.4" ID long bowl
wear ring.
2,864.0 2,864.0
11/27/2023
00:00
11/27/2023
01:30
1.50 SURFAC, WHDBOP PRTS P Fill BOP with mud and close blinds. Test
casing to 2,600 psi for 30 minutes.
Charted on Totco. Pumped 5.2 bbls and
bled back 4.5 bbls.
2,864.0 2,864.0
11/27/2023
01:30
11/27/2023
02:45
1.25 SURFAC, DRILLOUT BHAH P PJSM. M/U 12-1/4" INT 1 BHA as per
SLB DD T/409'. Monitor displacement
on trip tank.
0.0 409.0
11/27/2023
02:45
11/27/2023
04:00
1.25 SURFAC, DRILLOUT TRIP P RIH with INT 1 BHA on 5-7/8" DP
T/2,504'. Monitor displacement on trip
tank.
409.0 2,504.0
11/27/2023
04:00
11/27/2023
04:30
0.50 SURFAC, DRILLOUT CIRC P Fill pipe, shallow hole test MWD tools at
750 gpm with 790 psi - good test.
2,504.0 2,504.0
11/27/2023
04:30
11/27/2023
05:15
0.75 SURFAC, DRILLOUT REAM P Wash/Ream F/ 2,504' to 2,772' and tag
top plug.
750 GPM
820 PSI
40 RPM
7K TQ
P/U 152K
S/O 129K
ROT 139K
SPR's @ 2,772' MD / 2,361' TVD MW
10.4 ppg Time: 05:15 hrs
#1 MP 20 SPM @ 50 psi / 30 SPM @
70 psi
#2 MP 20 SPM @ 50 psi / 30 SPM @
70 psi
2,504.0 2,772.0
11/27/2023
05:15
11/27/2023
07:30
2.25 SURFAC, DRILLOUT DDRL P Drill out plugs and float collar F/2,772'
T/2,776' and cement T/2,862'. Ream
through float collar 2 times.
750 GPM
790 PSI
40 RPM
8K TQ
5-7K WOB
2,772.0 2,862.0
11/27/2023
07:30
11/27/2023
10:30
3.00 SURFAC, DRILLOUT DDRL P Drill out shoe and clean out rat hole
F/2,862' T/2,872'. Ream through shoe 3
times.
600-700 GPM
550-720 PSI
60-80 RPM
4-15K TQ
4-10K WOB
2,862.0 2,872.0
11/27/2023
10:30
11/27/2023
11:00
0.50 SURFAC, DRILLOUT DDRL P Drill 20' new formation F/2,872' T/2,892'.
850 GPM
1022 PSI
80 RPM
5-8K TQ
2-6K WOB
140K ROT
2,872.0 2,892.0
11/27/2023
11:00
11/27/2023
11:30
0.50 SURFAC, DRILLOUT CIRC P Circulate bottoms up while rotating and
reciprocating.
850 GPM
1022 PSI
80 RPM
5-8K TQ
140K ROT
2,892.0 2,814.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 8/37
CD4-587
Report Printed: 1/24/2024
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)
11/27/2023
11:30
11/27/2023
11:45
0.25 SURFAC, DRILLOUT LOT P Blow down top drive. R/U for FIT/LOT
and purge air from lines.
2,814.0 2,814.0
11/27/2023
11:45
11/27/2023
12:15
0.50 SURFAC, DRILLOUT LOT P Perform FIT/LOT. Pumped 2.3 bbls (19
stks) with 10.2 ppg mud, 800 psi,
observed break over, shut down,
monitor shut in pressure for 10 minutes,
bled down to 245 psi. EMW = 16.6 pg.
Bled back 1 bbl to trip tank.
2,814.0 2,814.0
11/27/2023
12:15
11/27/2023
12:45
0.50 SURFAC, DRILLOUT LOT P R/D and blow down lines. Pump up
MWD data for LOT at 750 gpm with 823
psi.
2,814.0 2,814.0
11/27/2023
12:45
11/27/2023
13:00
0.25 SURFAC, DRILLOUT CIRC P Wash/ream to 2,891'.
750 GPM
820 PSI
40 RPM
4-7K TQ
140K ROT
2,814.0 2,891.0
11/27/2023
13:00
11/27/2023
14:15
1.25 INTRM1, DRILL DISP P PJSM. Displace well to 10.8 ppg FWP.
Take SPR's.
1000 GPM
90 RPM
4-8K TQ
141K P/U
138K S/O
140K ROT
SPR's @ 2,892' MD / 2,397' TVD MW
10.8 ppg Time: 14:00 hrs
#1 MP 20 SPM @ 70 psi / 30 SPM @
85 psi
#2 MP 20 SPM @ 68 psi / 30 SPM @
88 psi
2,891.0 2,892.0
11/27/2023
14:15
11/27/2023
18:00
3.75 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
2,892' T/ 3,236' MD, 2,553' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1200 GPM
1650 PSI
160 RPM
5-8K TQ
3-15K WOB
11.22 ECD
BIT 3.45
JARS 19.37 hrs
ADT 3.45
2,892.0 3,236.0
11/27/2023
18:00
11/28/2023
00:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
3,236' T/ 3,833' MD, 2,724' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1200 GPM
1845 PSI
160 RPM
7K ON / 2K OFF TQ
7K WOB
11.38 ECD
BIT 8.14
JARS 24.06 hrs
ADT 4.69
3,236.0 3,833.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 9/37
CD4-587
Report Printed: 1/24/2024
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)
11/28/2023
00:00
11/28/2023
06:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
3,833' T/ 4,431' MD, 2,806' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1200 GPM
2070 PSI
160 RPM
7K ON / 2K OFF TQ
6K WOB
11.54 ECD
P/U 144K
S/O 134K
ROT 137K
BIT 12.75
JARS 28.67 hrs
ADT 4.61
3,833.0 4,431.0
11/28/2023
06:00
11/28/2023
12:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
4,431' T/ 5,006' MD, 2,884' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1200 GPM
2300 PSI
170 RPM
6-9K ON / 5-7K OFF TQ
3-20K WOB
11.70 ECD
P/U 145K
S/O 135K
ROT 140K
BIT 17.31
JARS 33.23 hrs
ADT 4.56
Max Gas 30
4,431.0 5,006.0
11/28/2023
12:00
11/28/2023
18:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
5,006' T/ 5,575' MD, 2,963' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1300 GPM
2740 PSI
170 RPM
6-11K ON / 6-7K OFF TQ
6-9K WOB
11.90 ECD
P/U 150K
S/O 133K
ROT 139K
BIT 21.80
JARS 33.23 hrs
ADT 4.56
Max Gas 130
SPR's @ 5412' MD / 2935' TVD, MW =
10.8 ppg @ 16:00 hrs
#1 MP 20 SPM = 130 PSI - 30 SPM =
160 PSI
#2 MP 20 SPM = 135 PSI - 30 SPM =
162 PSI
5,006.0 5,575.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 10/37
CD4-587
Report Printed: 1/24/2024
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)
11/28/2023
18:00
11/29/2023
00:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
5,575' T/ 6,096' MD, 3,037' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
Note: Started 475 bbl new mud dilution
at 6,050'.
1300 GPM
2990 PSI
170 RPM
9K ON / 2K OFF TQ
4K WOB
12.15 ECD
P/U 158K
S/O 135K
ROT 141K
BIT 26.43
JARS 42.45 hrs
ADT 4.63
Max Gas 79
5,575.0 6,096.0
11/29/2023
00:00
11/29/2023
06:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
6,096' T/ 6,587' MD, 3,101' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
Note: Started 475 bbl new mud dilution
at 6,050' and completed 6,140'.
1300 GPM
2994 PSI
170 RPM
12K ON / 3K OFF TQ
4-6K WOB
ECD 11.93
P/U 151K
S/O 138K
ROT 142K
BIT 31.22
JARS 47.14 hrs
ADT 4.79
Max Gas 174
SPR's @ 5,340' MD / 3,072' TVD, MW =
10.8 ppg @ 03:30 hrs
#1 MP 20 SPM = 145 PSI - 30 SPM =
175 PSI
#2 MP 20 SPM = 150 PSI - 30 SPM =
180 PSI
6,096.0 6,587.0
11/29/2023
06:00
11/29/2023
12:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
6,587' T/ 7,154' MD, 3,179' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1300 GPM
3248 PSI
170 RPM
11-15K ON / 7-10K OFF TQ
8-20K WOB
ECD 12.06
P/U 167K
S/O 137K
ROT 145K
BIT 35.8
JARS 51.72 hrs
ADT 4.58
Max Gas 82
6,587.0 7,154.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 11/37
CD4-587
Report Printed: 1/24/2024
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)
11/29/2023
12:00
11/29/2023
18:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
7,154' T/ 7,730' MD, 3,259' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1300 GPM
3353 PSI
170 RPM
11-14K ON / 5-12K OFF TQ
7-10K WOB
ECD 12.05
P/U 172K
S/O 128K
ROT 146K
BIT 40.25
JARS 56.17 hrs
ADT 4.45
Max Gas 124
SPR's @ 7,543' MD / 3,217' TVD, MW =
10.8 ppg @ 15:00 hrs
#1 MP 20 SPM = 160 PSI - 30 SPM =
188 PSI
#2 MP 20 SPM = 155 PSI - 30 SPM =
185 PSI
7,154.0 7,730.0
11/29/2023
18:00
11/30/2023
00:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
7,730' T/ 8,323' MD, 3,330' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1300 GPM
3455 PSI
170 RPM
14K ON / 5K OFF TQ
6-9K WOB
ECD 11.94
P/U 168K
S/O 143K
ROT 145K
BIT 44.77
JARS 60.69 hrs
ADT 4.52
Max Gas 152
7,730.0 8,323.0
11/30/2023
00:00
11/30/2023
06:00
6.00 INTRM1, DRILL DRLG P Drilled 12-1/4" intermediate section F/
8,323' T/ 8,932' MD, 3,394' TVD.
Pumped 40 bbl anti-bit balling sweeps
every other stand.
1300 GPM
3573 PSI
170 RPM
14K ON / 6K OFF TQ
6-10K WOB
ECD 11.98
P/U 173K
S/O 139K
ROT 153K
BIT 49.45
JARS 65.37 hrs
ADT 4.68
Max Gas 177
8,323.0 8,932.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 12/37
CD4-587
Report Printed: 1/24/2024
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)
11/30/2023
06:00
11/30/2023
12:00
6.00 INTRM1, DRILL DDRL P Drilled 12-1/4" intermediate section F/
8,932' T/ 9,361' MD, 3,454' TVD to
section TD. Pumped 40 bbl anti-bit
balling sweeps every other stand.
Note: Started 700 bbl new mud dilution
at 9,250' and completed at 9,346'.
1300 GPM
3324 PSI
170 RPM
14-16K ON / 10-12K OFF TQ
5-9K WOB
ECD 12.12
P/U 184K
S/O 118K
ROT 150K
BIT 54.05
JARS 69.97 hrs
ADT 4.6
Max Gas 142
8,932.0 9,361.0
11/30/2023
12:00
11/30/2023
12:15
0.25 INTRM1, TRIPCAS CIRC P Obtain final survey, final T&D and
SPR's.
SPR's @ 9,361' MD / 3,454' TVD, MW =
10.8 ppg @ 12:15 hrs
#1 MP 20 SPM = 215 PSI - 30 SPM =
235 PSI
#2 MP 20 SPM = 210 PSI - 30 SPM =
240 PSI
9,361.0 9,361.0
11/30/2023
12:15
11/30/2023
13:00
0.75 INTRM1, TRIPCAS BKRM P BROOH F/9,361' T/9,306' while
circulating bottoms up.
1300 GPM
3550 PSI
170 RPM
9-11K OFF TQ
ROT 140K
9,361.0 9,306.0
11/30/2023
13:00
11/30/2023
13:15
0.25 INTRM1, TRIPCAS OWFF P OWFF - static. 9,306.0 9,306.0
11/30/2023
13:15
11/30/2023
18:00
4.75 INTRM1, TRIPCAS BKRM P BROOH w/NOVOS F/9,306' T/8,041'.
1300 GPM
3550 PSI
170 RPM
9-11K TQ
ROT 140K
9,306.0 8,043.0
11/30/2023
18:00
12/1/2023
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH w/NOVOS F/8,041' T/6,100'.
1300 GPM
2917 PSI
170 RPM
9-10K TQ
ROT 135K
8,043.0 6,100.0
12/1/2023
00:00
12/1/2023
06:00
6.00 INTRM1, TRIPCAS BKRM P BROOH w/NOVOS F/6,100' T/4,481'.
1300 GPM
2565 PSI
170 RPM
9K TQ
ROT 135K
6,100.0 4,481.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 13/37
CD4-587
Report Printed: 1/24/2024
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)
12/1/2023
06:00
12/1/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH w/NOVOS F/4,481' T/2,907'.
1300 GPM
1485 PSI
170 RPM
6K TQ
ROT 128K
4,481.0 2,907.0
12/1/2023
12:00
12/1/2023
16:00
4.00 INTRM1, TRIPCAS BKRM P BROOH w/NOVOS F/2,907' T/1,700'.
Pumped nut plug sweep.
1300 GPM
2043 PSI
100 RPM
3K TQ
ROT 120K
2,907.0 1,700.0
12/1/2023
16:00
12/1/2023
16:30
0.50 INTRM1, TRIPCAS CIRC P Circulate and reciprocate out sweep
until shakers clean.
1300 GPM
2022 PSI
100 RPM
2K TQ
ROT 120K
1,700.0 1,700.0
12/1/2023
16:30
12/1/2023
17:00
0.50 INTRM1, TRIPCAS OWFF P OWFF - static. SIMPOS: blow down top
drive and prepare to POOH on
elevators.
1,700.0 1,700.0
12/1/2023
17:00
12/1/2023
18:00
1.00 INTRM1, TRIPCAS TRIP P POOH F/1,700' T/150'. monitor hole fill
on trip tank.
1,700.0 150.0
12/1/2023
18:00
12/1/2023
18:15
0.25 INTRM1, TRIPCAS OWFF P OWFF - static. PJSM for handling BHA. 150.0 150.0
12/1/2023
18:15
12/1/2023
20:00
1.75 INTRM1, TRIPCAS BHAH P POOH L/D BHA as per SLB DD. Monitor
hole fill on trip tank.
150.0 0.0
12/1/2023
20:00
12/1/2023
20:30
0.50 INTRM1, CASING WWWH P M/U stack wash tool on stand DP and
wash stack at 1250 gpm. L/D stack
wash tool.
0.0 0.0
12/1/2023
20:30
12/1/2023
22:00
1.50 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.
0.0 0.0
12/1/2023
22:00
12/1/2023
23:00
1.00 INTRM1, CASING MPSP P Pull wear ring and set test plug with 9-
5/8" test joint as per FMC Rep. Flood all
surface lines and stack with water.
Prepare for 9-5/8" rams test.
0.0 0.0
12/1/2023
23:00
12/1/2023
23:30
0.50 INTRM1, CASING PRTS P Test upper 9-5/8" solid body rams, 250
psi / 3,850 psi for 5 min.
0.0 0.0
12/1/2023
23:30
12/2/2023
00:00
0.50 INTRM1, CASING MPSP P Pull test plug as per FMC Rep and drain
water from the stack. Blow down kill line,
lay down test joint and pups.
SIOMPS: Mobilize casing equipment to
rig floor.
0.0 0.0
12/2/2023
00:00
12/2/2023
00:30
0.50 INTRM1, CASING RURD P Continue mobilizing casing equipment to
rig floor.
0.0 0.0
12/2/2023
00:30
12/2/2023
00:45
0.25 INTRM1, CASING SVRG P Service and inspect top drive. 0.0 0.0
12/2/2023
00:45
12/2/2023
02:00
1.25 INTRM1, CASING RURD P M/U Volant tool, install bail extensions
and elevators. Install spider slips.
Mobilize casing hanger assy to floor.
0.0 0.0
12/2/2023
02:00
12/2/2023
03:00
1.00 INTRM1, CASING PUTB P PU 9-5/8" 47#, T-95, HYD 563 casing
shoe track joints T/170'. Check floats -
good. Bakerlok all connections to pin of
joint #4 and torque connections to 19K.
0.0 170.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 14/37
CD4-587
Report Printed: 1/24/2024
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)
12/2/2023
03:00
12/2/2023
06:00
3.00 INTRM1, CASING PUTB P RIH with 9-5/8" 47#, T95, HYD 563
intermediate 1 casing F/170' T/1,550' as
per tally. Torque connections to 16k ft-
lbs, fill on the fly with the volant, top off
every 10 joints monitoring displacement
on pit #4.
S/O = 127k
170.0 1,550.0
12/2/2023
06:00
12/2/2023
12:00
6.00 INTRM1, CASING PULD P RIH with 9-5/8" 47#, T95, HYD 563
intermediate 1 casing F/1,550' T/4,684'
as per tally. Torque connections to 16k ft
-lbs, fill on the fly with the Volant, top off
every 10 joints monitoring displacement
on pit #4.
Note: At 2,870' established circulation
to 150 GPM at 136 psi. P/U = 165K, S/O
= 160K, ROT = 161k, RPM = 20, TQ =
3K.
1,550.0 4,684.0
12/2/2023
12:00
12/2/2023
18:00
6.00 INTRM1, CASING PULD P RIH with 9-5/8" 47#, T95, HYD 563
intermediate 1 casing F/4,684' T/8,100'
as per tally. Torque connections to 16k ft
-lbs, fill on the fly with the Volant, top off
every 10 joints monitoring displacement
on pit #4.
S/O = 161K
4,684.0 8,100.0
12/2/2023
18:00
12/2/2023
20:15
2.25 INTRM1, CASING PULD P RIH with 9-5/8" 47#, T95, HYD 563
intermediate 1 casing F/8,100' T/9,294'
as per tally. Torque connections to 16k ft
-lbs, fill on the fly with the Volant, top off
every 10 joints monitoring displacement
on pit #4.
S/O = 160K
8,100.0 9,294.0
12/2/2023
20:15
12/2/2023
21:00
0.75 INTRM1, CASING PULD P M/U 9-5/8" FMC casing hanger as per
FMC rep. Torque pup below hanger to
16K. M/U landing joints and wash down
at 2.5 bpm, 352 psi, and land out casing
hanger. Shoe @ 9,355', Float Collar @
9,264'.
P/U = 235K
S/O = 167K
9,294.0 9,355.0
12/2/2023
21:00
12/2/2023
23:00
2.00 INTRM1, CEMENT CIRC P Circulate and condition mud staging up
rate. SIMOPS: Held PJSM for
cementing operations.
2.5 bpm / 300 psi
8 bpm / 371 psi
9,355.0 9,355.0
12/2/2023
23:00
12/2/2023
23:15
0.25 INTRM1, CEMENT RURD P Blew down top drive. Rigged up cement
hose to CRT swivel.
9,355.0 9,355.0
12/2/2023
23:15
12/2/2023
23:30
0.25 INTRM1, CEMENT CIRC P Circulate and condition mud staging up
rate to 5 bpm, 340 psi.
9,355.0 9,355.0
12/2/2023
23:30
12/3/2023
00:00
0.50 INTRM1, CEMENT CMNT P Lined up on cementers & pressure
tested lines to 4000 psi. Mix & pump
73.1 bbls of 12.00 ppg Mud Push II at 4
bpm; 272 psi.
9,355.0 9,355.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 15/37
CD4-587
Report Printed: 1/24/2024
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)
12/3/2023
00:00
12/3/2023
03:15
3.25 INTRM1, CEMENT CMNT P Loaded bottom plug. SLB pumped 165.1
bbls of 15.8 ppg G cement at 5.5 bpm;
350-210 psi. Loaded top plug. SLB
pumped 20 bbls of fresh water at 5.5
bpm, 122-64 psi. Swapped over to the
rig pump and chased cement with 10.8
ppg mud at 6 bpm, 248-670 psi.
Observed bottom plug land & burst with
508 bbls pumped. Observed top plug
bump with 672.8 bbls pumped.
Pressured up to 1100 psi & held for 5
minutes. Checked floats, good.
Observed minor losses with ~498 bbls
pumped. Total losses during
displacement 30 bbls. CIP 02:53 hrs.
9,355.0 0.0
12/3/2023
03:15
12/3/2023
03:45
0.50 INTRM1, CEMENT RURD P Blew down cement hose on the rig floor.
Rigged up to test casing.
0.0 0.0
12/3/2023
03:45
12/3/2023
04:30
0.75 INTRM1, CEMENT PRTS P Performed casing pressure test.
Pressured up to 3892 psi, pumping 9.4
bbls. Shut in and monitored pressure for
30 minutes. Initial shut in pressure 3892
psi; final shut in pressure 3872 psi. Bled
back 9.4 bbls.
0.0 0.0
12/3/2023
04:30
12/3/2023
05:00
0.50 INTRM1, CEMENT RURD P Blew down lines, rigged down test
equipment; cleared rig floor.
0.0 0.0
12/3/2023
05:00
12/3/2023
06:00
1.00 INTRM1, CEMENT RURD P Backed out landing joints and laid down
to pipe shed per FMC Rep. Rigged
down casing elevators, bail extensions,
& CRT. Cleared & cleaned rig floor.
0.0 0.0
12/3/2023
06:00
12/3/2023
07:30
1.50 INTRM1, WHDBOP WWWH P Made up stack wash tool to a stand of 5-
7/8" HWDP. Washed stack & wellhead.
SIMOPS continued to clean & clear rig
floor.
0.0 0.0
12/3/2023
07:30
12/3/2023
08:45
1.25 INTRM1, WHDBOP WWSP P Drained stack & blew down top drive.
Made up running tool to a stand of
HWDP. Set pack off as per FMC Rep.
Tested pack off to 5000 psi for 15
minutes, witnessed by CPAI Rep.
SIMOPS prepped rig floor for testing
BOPE.
0.0 0.0
12/3/2023
08:45
12/3/2023
10:00
1.25 INTRM1, WHDBOP RURD P Shut blind rams. De-energized
accumulator system. Changed upper
rams to 3-1/2" X 6-5/8" VBRs. SIMOPS
rigged down running tool; made up 4-
1/2" test joint, pups & test plug.
0.0 0.0
12/3/2023
10:00
12/3/2023
11:00
1.00 INTRM1, WHDBOP RURD P Set test plug with 4-1/2" test joint .
Flooded all surface lines with fresh
water & purged air. Performed shell test.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 16/37
CD4-587
Report Printed: 1/24/2024
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)
12/3/2023
11:00
12/3/2023
16:30
5.50 INTRM1, WHDBOP BOPE P Performed BOP test with 4-1/2" & 5-
7/8" test joints and charted all test.
Annular to 250/2500 psi, 5 min each.
Remaining tests 250/3850 psi, 5 min
each.
#1 Annular with 4-1/2" test joint to 250
psi low, 2500 psi high.
#2 Upper VBRs 3-1/2" x 6-5/8" with 4-
1/2" test joint; CMV 1,14, 15, 16; 4-1/2"
dart valve; kill line valve #3.
#3 4-1/2" FOSV; 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.
#7 CMV 2, 5-7/8" dart valve.
#8 HCR choke valve & 5-7/8" FOSV.
#9 Manual choke valve & upper IBOP.
#10 Lower VBRs 3-1/2" x 6-5/8" with 4-
1/2" test joint & lower IBOP.
#11 Blind / shear rams; CMV 3,4,6.
#12 Manual choke & super choke to
1500 psi.
#13 Upper 3-1/2" X 6-5/8" VBRs with 5-
7/8" test joint.
#14 Lower 3-1/2" X 6-5/8" VBRs with 5-
7/8" test joint.
Conducted accumulator draw down.
System pressure 3075 psi; manifold
pressure 1500 psi; after all closures
1700 psi; 200 psi build with 2 electric
pumps in 13 seconds; full pressure
attained in 86 seconds. Closing times:
annular 15 seconds; UPR 14 seconds;
blind/shear 15 seconds; LPR 14
seconds; choke HCR 1 second; kill HCR
1 second. 10 bottles nitrogen backup
3975 psi average. Gas detection
system, pit level indicators and flow
alarms tested. Test witness waived by
AOGCC, Austin McLeod.
0.0 0.0
12/3/2023
16:30
12/3/2023
17:00
0.50 INTRM1, WHDBOP RURD P Removed test plug. Drained BOP stack.
Made up running tool & set wear
bushing as per FMC Rep. Laid down
test joint & pups. Blew down surface
lines.
0.0 0.0
12/3/2023
17:00
12/3/2023
18:00
1.00 INTRM1, WHDBOP RURD P Cleared & cleaned rig floor. SIMOPS
prepped to pick up BHA #3.
0.0 0.0
12/3/2023
18:00
12/3/2023
19:45
1.75 INTRM1, DRILLOUT BHAH P Picked up 8-1/2" X 9-1/2" intermediate 2
BHA to 382' MD as per SLB DD.
0.0 382.0
12/3/2023
19:45
12/3/2023
22:00
2.25 INTRM1, DRILLOUT PULD P Tripped in the hole from 382'-2263' MD
picking up 60 singles from the shed.
Drifted to 2.75" SOW 105K
382.0 2,263.0
12/3/2023
22:00
12/3/2023
22:30
0.50 INTRM1, DRILLOUT CIRC P Filled drill pipe & performed shallow hole
test, good. Blew down top drive. 450
gpm; 1278 psi.
2,263.0 2,263.0
12/3/2023
22:30
12/4/2023
00:00
1.50 INTRM1, DRILLOUT PULD P Tripped in the hole from 2263'-3871' MD
picking up 51 singles from the shed.
Drifted to 2.75" SOW 98K
2,263.0 3,871.0
12/4/2023
00:00
12/4/2023
01:45
1.75 INTRM1, DRILLOUT PULD P Tripped in the hole on 4-1/2" DP from
3871'-5286' MD, picking up 45 singles
from the shed. Drifted to 2.75" SOW
97K.
3,871.0 5,286.0
12/4/2023
01:45
12/4/2023
02:00
0.25 INTRM1, DRILLOUT FRZP P Rigged up lines to the OA. Pressure
tested lines to 2000 psi. SIMOPS filled
pipe, blew down top drive & swapped
out handling equipment to 5-7/8".
5,286.0 5,286.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 17/37
CD4-587
Report Printed: 1/24/2024
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)
12/4/2023
02:00
12/4/2023
03:45
1.75 INTRM1, DRILLOUT FRZP P Performed LOT on the OA with LRS.
Pressured up to 759 psi with 11.5 bbls
of diesel. Pumped 3.5 bbls more for a
total of 15 bbls & shut in. Monitored
pressure for 10 minutes ISP 510 psi,
FSP 426 psi. Continued with freeze
protect, pumping 89 bbls total at 1.5
bpm, 500-874 psi. Shut down & rigged
down LRS lines. OA shut in pressure
834 psi.
SIMOPS tripped in the hole on 5-7/8"
DP from 5286'-7607' MD, fill every 5
stands, SOW 78-84K.
5,286.0 7,607.0
12/4/2023
03:45
12/4/2023
04:30
0.75 INTRM1, DRILLOUT TRIP P Tripped in the hole on 5-7/8" DP from
7607'-8441' MD, SOW 75-84K.
7,607.0 8,441.0
12/4/2023
04:30
12/4/2023
07:00
2.50 INTRM1, DRILLOUT REAM P Washed & reamed in the hole due to
loss of slack off weight from 8441'-9264'
MD.
500 gpm; 2481 psi
30 rpm; Tq 11K
ECD 12.94
RSOW 126K
8,441.0 9,264.0
12/4/2023
07:00
12/4/2023
07:45
0.75 INTRM1, DRILLOUT DRLG P Tagged plugs on float collar at 9264'
MD. Drilled from 9264'-9267' MD.
Reamed 3 times.
500 gpm; 2506 psi
50 rpm; Tq 18K
WOB 12-18K
ECD 12.64
9,264.0 9,267.0
12/4/2023
07:45
12/4/2023
08:15
0.50 INTRM1, DRILLOUT DRLG P Drilled cement from 9267'-9352' MD.
570 gpm; 3115 psi
50 rpm; Tq 18K
WOB 11K
ECD 12.87
9,267.0 9,352.0
12/4/2023
08:15
12/4/2023
10:45
2.50 INTRM1, DRILLOUT DRLG P Tagged shoe at 9352' MD. Drilled from
9352'-9361' MD. Reamed shoe 5 times.
500 gpm; 2300 psi
70 rpm; Tq 15K
WOB 7-20K
ECD 12.34
PUW 165K
SOW NA
RW 123K
9,352.0 9,361.0
12/4/2023
10:45
12/4/2023
11:30
0.75 INTRM1, DRILLOUT DDRL P Drilled 8-1/2" intermediate 2 section
from 9361'-9381' MD, 3457' TVD.
570 gpm; 2912 psi
80 rpm; Tq on 16K, off 13K
WOB 8-10K
ECD 12.95
PUW 165K
SOW NA
RW 123K
ADT .41; BIT .41; JARS 70.37 hrs
9,361.0 9,381.0
12/4/2023
11:30
12/4/2023
11:45
0.25 INTRM1, DRILLOUT BKRM P Backreamed from 9381'-9333' MD.
570 gpm; 2908 psi
80 rpm; Tq 15K
ECD 12.84
9,381.0 9,333.0
12/4/2023
11:45
12/4/2023
12:30
0.75 INTRM1, DRILLOUT CIRC P Circulated bottoms up, reciprocating.
600 gpm; 3217 psi
80 rpm; Tq 15K
ECD 12.94
9,333.0 9,333.0
12/4/2023
12:30
12/4/2023
13:00
0.50 INTRM1, DRILLOUT FIT P Performed FIT to a EMW of 14.0 ppg
with 10.5 ppg mud at 3453' TVD.
Pressured up to 625 psi with 2.0 bbls.
Shut in and monitored for 10 minutes,
with final pressure of 526 psi. Bled back
2.1 bbls.
9,333.0 9,333.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 18/37
CD4-587
Report Printed: 1/24/2024
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)
12/4/2023
13:00
12/4/2023
13:45
0.75 INTRM2, DRILL MPDA P Installed 5-7/8" MPD bearing as per
SOP & MPD Advisor.
9,333.0 9,333.0
12/4/2023
13:45
12/4/2023
14:30
0.75 INTRM2, DRILL REAM P Washed & reamed from 9333'-9381'
MD.
500 gpm; 2452 psi
40 rpm; Tq 15K
ECD 12.73
9,333.0 9,381.0
12/4/2023
14:30
12/4/2023
16:00
1.50 INTRM2, DRILL DISP P Displaced well to 9.0 ppg FWP mud
system per Mud Engineers procedure.
Pumped 783 bbls total. Performed MPD
ramps per Advisor.
700 gpm; 2713 psi
40 rpm; Tq 6K
ECD 11.96
MPD 230 psi
9,381.0 9,381.0
12/4/2023
16:00
12/4/2023
18:00
2.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section
from 9381'-9522' MD, 3477' TVD.
Obtained SCR.
700 gpm; 2770 psi
100 rpm; Tq on 13K, off 5K
WOB 10K
ECD 12.1
PUW 168K
SOW 118
RW 138K
ADT 1.23; BIT 1.64; JARS 71.60 hrs
9,381.0 9,522.0
12/4/2023
18:00
12/4/2023
18:45
0.75 INTRM2, DRILL CIRC P Opened SLB under reamer per
procedure. Obtained parameters prior to
dropping activation ball. Dropped 1.25"
activation ball & pumped down per SLB
procedure. Picked up to 9507' while
pumping. Ball on seat with 875 strokes,
103.9 bbls pumped. Obtained
parameters with reamer open.
Reamer closed-
710 gpm, 2805 psi; 50 rpm, Tq 4-6K;
4350 TRPM
Reamer opened-
710 gpm, 2395 psi; 50 rpm, Tq 6-8K;
4000 TRPM
9,522.0 9,507.0
12/4/2023
18:45
12/4/2023
19:00
0.25 INTRM2, DRILL BKRM P Backreamed from 9507'-9488' MD.
710 gpm; 2395 psi
80 rpm; Tq 8-10K
PUW 152K
SOW 111K
Shut down rotary & pull to 9585' MD to
observe 10K over pull. Reamed back
down to 9522' MD.
9,507.0 9,522.0
12/4/2023
19:00
12/5/2023
00:00
5.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section
from 9522'-10,015' MD, 3553' TVD.
705 gpm; 2508 psi
140 rpm; Tq on 16K, off 10K
WOB 17K
ECD 12.0
PUW 172K
SOW 112
RW 140K
ADT 3.63; BIT 5.27; JARS 75.23 hrs
9,522.0 10,015.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 19/37
CD4-587
Report Printed: 1/24/2024
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)
12/5/2023
00:00
12/5/2023
06:00
6.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section with
NOVOS from 10,015'-10,430' MD, 3616'
TVD. MPD held 12.0 EMW at the shoe.
Pumped anti bit-balling sweeps every
4th stand. Obtained SCR.
705 gpm; 2548 psi
150 rpm; Tq on 15K, off 5K
WOB 16K
ECD 12.15
PUW 172K
SOW 112K
RW 140K
ADT 4.48; BIT 9.75; JARS 79.71 hrs
10,015.0 10,430.0
12/5/2023
06:00
12/5/2023
12:00
6.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section with
NOVOS from 10,430'-11,069' MD, 3714'
TVD. MPD held 12.0 EMW at the shoe.
Pumped anti bit-balling sweeps every
4th stand.
700 gpm; 2622 psi
150 rpm; Tq on 16K, off 5K
WOB 12K
ECD 11.99
PUW 174K
SOW 115K
RW 145K
ADT 4.39; BIT 14.14; JARS 84.10 hrs
10,430.0 11,069.0
12/5/2023
12:00
12/5/2023
18:00
6.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section with
NOVOS from 11,069'-11,635' MD, 3798'
TVD. MPD held 12.0 EMW at the shoe.
Pumped anti bit-balling sweeps every
4th stand. Obtained SCR.
700 gpm; 2693 psi
150 rpm; Tq on 15K, off 5K
WOB 13K
ECD 12.36
PUW 177K
SOW 112K
RW 144K
ADT 4.36; BIT 18.5; JARS 88.46 hrs
11,069.0 11,635.0
12/5/2023
18:00
12/6/2023
00:00
6.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section with
NOVOS from 11,635'-12,201' MD, 3882'
TVD. MPD held 12.0 EMW at the shoe.
Pumped anti bit-balling sweeps every
4th stand. Obtained SCR.
700 gpm; 2734 psi
140-150 rpm; Tq on 14K, off 6K
WOB 14K
ECD 11.99
PUW 177K
SOW 113K
RW 146K
ADT 4.49; BIT 22.99; JARS 92.95 hrs
11,635.0 12,201.0
12/6/2023
00:00
12/6/2023
06:00
6.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section with
NOVOS from 12,201'-12,798' MD,
3,969' TVD. MPD held 12.0 EMW at the
shoe. Pumped anti bit-balling sweeps
every 4th stand. Obtained SCR.
700 gpm; 2690 psi
150 rpm; Tq on 14K, off 7K
WOB 16K
ECD 12.29
PUW 182K
SOW 118K
RW 145K
ADT 4.23; BIT 27.22; JARS 97.18 hrs
SIMOPS: Build stands 4-1/2" DP and
rack back (10 stds in 3 Hrs)
12,201.0 12,798.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 20/37
CD4-587
Report Printed: 1/24/2024
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)
12/6/2023
06:00
12/6/2023
12:00
6.00 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section with
NOVOS from 12,798'-13,421' MD,
4,047' TVD. MPD held 12.0 EMW at the
shoe. Pumped anti bit-balling sweeps
every 4th stand. Obtained SCR.
700 gpm; 2739 psi
150 rpm; Tq on 15K, off 7K
WOB 13K
ECD 12.38
PUW 184K
SOW 116K
RW 153K
ADT 4.29; BIT 31.51; JARS 101.47 hrs
SIMOPS: Build stands 4-1/2" DP and
rack back (20 stds in 6 Hrs)
12,798.0 13,421.0
12/6/2023
12:00
12/6/2023
13:45
1.75 INTRM2, DRILL DDRL P Drilled 8-1/2" intermediate 2 section with
NOVOS from 13,421'-13,599' MD,
4,066' TVD. MPD held 12.0 EMW at the
shoe. Pumped anti bit-balling sweeps
every 4th stand.
700 gpm; 2757 psi
150 rpm; Tq on 15K, off 7K
WOB 15K
ECD 12.42
PUW 183K
SOW 118K
RW 155K
ADT 1.27; BIT 32.78; JARS 102.74 hrs
SIMOPS: Build stands 4-1/2" DP and
rack back
13,421.0 13,599.0
12/6/2023
13:45
12/6/2023
14:15
0.50 INTRM2, TRIPCAS CIRC P Geo called TD at 13,599' MD, 4,066'
TVD. Obtain final survey, T&D, SPR's.
PUW 183K
SOW 118K
RW 155K
13,599.0 13,599.0
12/6/2023
14:15
12/6/2023
15:00
0.75 INTRM2, TRIPCAS CIRC P Pump down 1.625" steel ball to close
under reamer as per DD. Pump at 250
gpm, 1,025 psi, 900 stks, 100 gpm, 790
psi, ball on seat at 1349 stks, shear at
2,343 psi. 700 GPM, 2,950 psi, 3,672
TRPM, confirm reamer closed.
13,599.0 13,599.0
12/6/2023
15:00
12/6/2023
16:00
1.00 INTRM2, TRIPCAS CIRC P Circ & Recip F/13,595' to 13,500' MD,
700 GPM, 2,930 PSI, 9K TQ, 23% FO,
12.37 ECD, 6,800 total stks pumped
13,599.0 13,599.0
12/6/2023
16:00
12/6/2023
18:45
2.75 INTRM2, TRIPCAS OWFF P Blow down TD, line up on TT. Conduct
MPD drawdown. 490 PSI MPD start,
holding chokes open longer as returns
diminish, 250 PSI final stabilized, 44 bbl
total gain
SIMOPS: Continue build stds 4-1/2" DP
and stand back in derrick
13,599.0 13,599.0
12/6/2023
18:45
12/6/2023
21:30
2.75 INTRM2, TRIPCAS OWFF P Open choke, monitor on TT. Observe
well bleed back, initial 6 bph to 1 bph.
51 bbl total gain.
13,599.0 13,599.0
12/6/2023
21:30
12/7/2023
00:00
2.50 INTRM2, TRIPCAS OWFF P Line up to observe bleed back off MPD
head in BOP deck. Initial 1.19 bph to .5
bph
13,599.0 13,599.0
12/7/2023
00:00
12/7/2023
06:30
6.50 INTRM2, TRIPCAS OWFF P Continue observe well with slowly
diminishing flow back. .5 BPH to .14 bph
13,599.0 13,599.0
12/7/2023
06:30
12/7/2023
08:00
1.50 INTRM2, TRIPCAS CIRC P Circulate and weight up from 9.0 to 9.3
ppg.
500 GPM, 1740 PSI, 30 RPM, 5K TQ,
26% FO, 11.35 ECD, 27 units max gas.
13,599.0 13,537.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 21/37
CD4-587
Report Printed: 1/24/2024
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)
12/7/2023
08:00
12/7/2023
12:00
4.00 INTRM2, TRIPCAS BKRM P BROOH F/13,537' to 12,472' MD. 700
GPM, 2884 PSI, 120 RPM, 10K TQ,
30% FO, 12.46 ECD, 136K RTW, MPD
holding 12.0 EMW at shoe on
connections.
13,537.0 12,472.0
12/7/2023
12:00
12/7/2023
18:00
6.00 INTRM2, TRIPCAS BKRM P BROOH F/12,472' to 10,680' MD. 700
GPM, 2729 PSI, 120 RPM, 11K TQ,
27% FO, 12.06 ECD, 134K RTW, MPD
holding 12.0 EMW at shoe on
connections.
12,472.0 10,680.0
12/7/2023
18:00
12/7/2023
22:15
4.25 INTRM2, TRIPCAS BKRM P BROOH F/10,680' to 9,551' MD. 700
GPM, 2706 PSI, 120 RPM, 10-12K TQ,
36% FO, 12.02 ECD, 134K RTW, MPD
holding 12.0 EMW at shoe on
connections. Reduce parameters w/ pull
BHA into casing f/ 9,551' to 9,351' MD to
500 GPM, 1711 PSI, 80 RPM, 6-10K Tq,
11.98 ECD
10,680.0 9,351.0
12/7/2023
22:15
12/7/2023
22:45
0.50 INTRM2, TRIPCAS CIRC P Rot & Recip W/ Circ hole clean with 700
GPM, 2685 PSI, 35% FO, 100 RPM, 9-
11K Tq, 11.62 ECD, 138K RTW
9,351.0 9,272.0
12/7/2023
22:45
12/8/2023
00:00
1.25 INTRM2, TRIPCAS OWFF P Shut down pumps, hold 300 PSI w/ line
up on TT. Bleed off 50 psi at a time,
open chokes to trip tank and monitor
diminishing return rate. Initial at 28 bph
to 13 bph. Total volume breathed back
38 bbls
9,272.0 9,272.0
12/8/2023
00:00
12/8/2023
04:00
4.00 INTRM2, TRIPCAS OWFF P Contnue OWFF monitoring diminishing
bleed back rate to TT. 13 bph to 1.6 bph.
Total 53 bbl bled back.
9,272.0 9,272.0
12/8/2023
04:00
12/8/2023
05:30
1.50 INTRM2, TRIPCAS SMPD P SOOH F/ 9,272' T/ 8,532' MD per MPD
schedule maintaining 12.0 ppg EMW at
9-5/8" shoe. Observe 15K overpull. SIH
t/ 8,565', pick back up t/ 8,532', no
overpull.
9,272.0 8,532.0
12/8/2023
05:30
12/8/2023
06:00
0.50 INTRM2, TRIPCAS BKRM P BROOH F/8,532' T/8,420'MD W/ CBU.
Maintain 12.0 EMW, 550 GPM, 1921
PSI, 35% FO, 100 RPM, 7-10K Tq,
129K PU RTW
8,532.0 8,420.0
12/8/2023
06:00
12/8/2023
07:00
1.00 INTRM2, TRIPCAS BKRM P BROOH F/ 8'420' T/ 8,254' MD.
Maintaining 12.0 EMW at shoe. 700
GPM, 2764 PSI, 23% FO, 100 RPM, 6K
Tq, 128K PU RTW
8,420.0 8,254.0
12/8/2023
07:00
12/8/2023
10:00
3.00 INTRM2, TRIPCAS SMPD P SOOH F/ 8,254' T/ 5,382' MD per MPD
schedule maintaining 12.0 ppg EMW at
9-5/8" shoe. 127K PUW, 113K SOW
8,254.0 5,382.0
12/8/2023
10:00
12/8/2023
11:15
1.25 INTRM2, TRIPCAS MPDA P PJSM, OWFF, Swap MPD
bearing/element from 5-7/8" to 4-1/2"
per SOP
5,382.0 5,382.0
12/8/2023
11:15
12/8/2023
12:00
0.75 INTRM2, TRIPCAS SMPD P SOOH F/ 5,382' T/ 4,537' MD per MPD
schedule maintaining 12.0 ppg EMW at
9-5/8" shoe. 123K PUW
5,382.0 4,537.0
12/8/2023
12:00
12/8/2023
15:30
3.50 INTRM2, TRIPCAS SMPD P SOOH F/ 4,537' T/ 476' MD per MPD
schedule maintaining 12.0 ppg EMW at
9-5/8" shoe. 101K PUW. 29 bbl hole fill,
32 bbl calculated
4,537.0 476.0
12/8/2023
15:30
12/8/2023
16:15
0.75 INTRM2, TRIPCAS MPDA P PJSM, flow check, remove 4-1/2" RCD
bearing per SOP
476.0 476.0
12/8/2023
16:15
12/8/2023
18:00
1.75 INTRM2, TRIPCAS BHAH P POOH w/ 4-1/2" DP F/ 476' to 189' MD.
Monitor hole fill VIA TT. LD jars and
replace with joint HWDP, rack back 2
stds HWDP.
476.0 189.0
12/8/2023
18:00
12/8/2023
20:30
2.50 INTRM2, TRIPCAS BHAH P LD Int 2 BHA F/ 189' per SLB DD.
Monitor hole fill via TT, Gauge stabs and
bit.
189.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 22/37
CD4-587
Report Printed: 1/24/2024
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)
12/8/2023
20:30
12/8/2023
21:15
0.75 INTRM2, CASING WWWH P MU 1 std 5-7/8" DP, wash wear ring and
BOP stack. 1200 GPM, 30 PSI, 10
RPM, LD stack washer
0.0 0.0
12/8/2023
21:15
12/8/2023
21:45
0.50 INTRM2, CASING RURD P Drain stack, MU wear ring running tool,
pull wear ring per FMC rep/SOP
0.0 0.0
12/8/2023
21:45
12/9/2023
00:00
2.25 INTRM2, CASING RURD P Close blind rams, power down Koomy,
open upper ram doors, CO VBRs to 7-
5/8" solid body rams, MU test plug and
set, fill stack.
SIMOPS: PU casing equip to RF
0.0 0.0
12/9/2023
00:00
12/9/2023
01:00
1.00 INTRM2, CASING BOPE P Fill BOP stack and test equip with water,
test 7-5/8" solid body rams 250 psi low,
3850 psi high 5 min each. Witness
waived by AOGCC Kam St John.
0.0 0.0
12/9/2023
01:00
12/9/2023
01:45
0.75 INTRM2, CASING RURD P RD test equip, install wear ring per FMC
rep, LD 7-5/8 test jt, WR ID = 8.66"
0.0 0.0
12/9/2023
01:45
12/9/2023
03:00
1.25 INTRM2, CASING RURD P Clean/Clear floor, RU casing equip with
Volant.
0.0 0.0
12/9/2023
03:00
12/9/2023
06:00
3.00 INTRM2, CASING PUTB P RIH w/ 7-5/8", 29.7/39#, L80/P110,
H523 liner as per tally to 320'. Check
floats.
0.0 320.0
12/9/2023
06:00
12/9/2023
06:30
0.50 INTRM2, CASING PUTB P RIH w/ 7-5/8", 29.7/39#, L80/P110,
H523 liner as per tally F/ 320' to 627'
MD'. Fill on the fly, top off every 10.
Monitor displacement on Pit #5. 93K
SOW
320.0 627.0
12/9/2023
06:30
12/9/2023
06:45
0.25 INTRM2, CASING RURD P Change out Volant swab cup from 39#
to 29.7#
627.0 627.0
12/9/2023
06:45
12/9/2023
12:00
5.25 INTRM2, CASING PUTB P RIH w/ 7-5/8", 29.7#, L80, H523 liner as
per tally F/ 627' to 3,263' MD'. Fill on the
fly, top off every 10. Monitor
displacement on Pit #5. 185K PUW, 82K
SOW.
627.0 3,263.0
12/9/2023
12:00
12/9/2023
13:00
1.00 INTRM2, CASING PUTB P Change out bad Jts #83 and 82. 3,263.0 3,263.0
12/9/2023
13:00
12/9/2023
15:00
2.00 INTRM2, CASING PUTB P RIH w/ 7-5/8", 29.7#, L80, H523 liner as
per tally F/ 3,263' to 4,370' MD. Fill on
the fly, top off every 10. Monitor
displacement on Pit #5.
3,263.0 4,370.0
12/9/2023
15:00
12/9/2023
16:00
1.00 INTRM2, CASING RURD P RD Volant and casing equipment, blow
down TD, prep to PU Dril-Quip liner
hanger off scud launcher.
4,370.0 4,370.0
12/9/2023
16:00
12/9/2023
17:00
1.00 INTRM2, CASING PUTB P PU Dril-Quip liner hanger assembly, MU
to liner with casing tongs. MU stand of 5
-7/8" DP to liner hanger assy. Obtain
parameters, 196K PUW, 85K SOW,
110K RTW, 4-6K TQ.
4,370.0 4,428.0
12/9/2023
17:00
12/9/2023
18:30
1.50 INTRM2, CASING CIRC P Circulate liner volume. 5 BPM, 484 PSI. 4,428.0 4,428.0
12/9/2023
18:30
12/10/2023
00:00
5.50 INTRM2, CASING RUNL P RIH w/ 7-5/8" liner on 5-7/8" DP F/
4,428' to 7,116' MD. Rotated down from
5,276' MD. 20 RPM, 6-7K Tq, Fill on the
fly and top off every 10 stds. Monitor
dispacement on pit 5.
4,428.0 7,116.0
12/10/2023
00:00
12/10/2023
06:00
6.00 INTRM2, CASING RUNL P RIH w/ 7-5/8" liner on 5-7/8" DP F/
7,116' to 9,434' MD. 20 RPM, Obtain
T&D at shoe, 100 GPM, 580 PSI, 176K
PUW, 131K RTW, 87K SORTW, 20
RPM, 11K Tq. Fill on the fly and top off
every 10 stds. Monitor displacement on
pit 5.
7,116.0 9,434.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 23/37
CD4-587
Report Printed: 1/24/2024
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)
12/10/2023
06:00
12/10/2023
12:00
6.00 INTRM2, CASING RUNL P Wash and Ream in hole w/ 7-5/8" liner
on 5-7/8" DP F/ 9,434' to 12,050' MD. 20
RPM, 9K Tq, 100 GPM, 563 PSI, 130K
RTW, Monitor displacement on pit 5.
9,434.0 12,050.0
12/10/2023
12:00
12/10/2023
12:30
0.50 INTRM2, CASING RUNL P Wash and Ream in hole w/ 7-5/8" liner
on 5-7/8" DP F/ 12,050' to 12,310' MD.
20 RPM, 9K Tq, 100 GPM, 566 PSI,
135K RTW, Monitor displacement on pit
5.
12,050.0 12,310.0
12/10/2023
12:30
12/10/2023
14:00
1.50 INTRM2, CASING RUNL P RIH w/ 7-5/8" liner on 5-7/8" DP and 5-
7/8 HWDP F/ 12,310' to 13,477' MD no
rotary, 125K SOW. Fill on the fly and top
off every 10 stds. Monitor displacement
on pit 5.
12,310.0 13,477.0
12/10/2023
14:00
12/10/2023
14:30
0.50 INTRM2, CASING RUNL P Wash and Ream in hole w/ 7-5/8" liner
on 5-7/8" DP F/ 13,477' to 13,597' MD.
20 RPM, 12K Tq, 100 GPM, 690 PSI,
146K RTW, Monitor displacement on pit
5.
13,477.0 13,597.0
12/10/2023
14:30
12/10/2023
16:15
1.75 INTRM2, CEMENT CIRC P Circ and condition mud for cement w/
rotate and reciprocate. Stage up pump
rate to 5.9 BPM, 652 PSI, 20 RPM, 9K
TQ, 215K PUW, 148K SOW, 166K
RTW, 4300 total stks
13,597.0 13,597.0
12/10/2023
16:15
12/10/2023
18:00
1.75 INTRM2, CEMENT RURD P PJSM, Blow down TD, PU Citadel plug
head, MU valves and cement hose,
noticed torque issues w/ screwing into
Citadel head with TD. LD Citadel head
as threads are compromised.
13,597.0 13,597.0
12/10/2023
18:00
12/10/2023
18:30
0.50 INTRM2, CEMENT RURD T LD Citadel head and cement equip 13,597.0 13,597.0
12/10/2023
18:30
12/10/2023
19:30
1.00 INTRM2, CEMENT RURD T C/O TD saver sub, MU new 5-7/8" saver
sub. Tq to 86K, MU Tq ring per SOP
13,597.0 13,597.0
12/10/2023
19:30
12/10/2023
20:30
1.00 INTRM2, CEMENT CIRC P RU head pin and cement line, establish
circ rate and pressure with head pin,
stage up flow rate to 6.0 BPM, 760 PSI
13,597.0 13,597.0
12/10/2023
20:30
12/11/2023
00:00
3.50 INTRM2, CEMENT CMNT P PJSM on cementing, Line up to SLB,
pump 5 bbls H20. PT to 6500 psi, SLB
pump 40 bbls 12.0 ppg mud push, break
head pin, load bottom dart, SLB pump
131 bbls 15.8 ppg G cement, break
head pin, load top dart, SLB pump 20
bbls H2O, take over with rig pump. Rig
displace with 9.3+ ppg mud at 6 bpm.
PU Btm LWP at 555 stks with 667 psi to
shear at 3 bpm, continue displace at 6
bpm, at 1483 stks break head pin and
load Bozo plug, continue displace at 6
bpm, PU top LWP at 1668 stks with
1702 psi to shear at 4.3 bpm, continue
displace at 6 bpm, shear btm LWP at LC
at 2188 stks with 2421 psi at 2.7 bpm,
continue displace at 6 bpm, slow to 5
bpm at 2527 stks, 4.0 bpm at 2780 stks,
3.0 bpm at 3201 stks, bump plug at
3303 stks, increase pressure to 500 psi
over final displacement pressure to
1448 psi for 5 min, bleed off and check
floats ok. No losses to formation. CIP at
2346 hrs.
13,597.0 13,597.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 24/37
CD4-587
Report Printed: 1/24/2024
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)
12/11/2023
00:00
12/11/2023
01:45
1.75 INTRM2, CEMENT PACK P Set Dril-Quip hanger per Rep, confirm
hanger set w/ 75K overpull. 285K PUW,
SO 30K at tool, hold 5 min at 100K.
Close annular, pump down annulus and
test liner top to 2000 psi for 10 min ok,
bleed off presure, open annular, PU and
shear out liner hanger w/ 20 K over pull,
205K PUW. LD 2 Jts DP to shed.
Pressure up and blow ball seat with
6,397 psi.
13,597.0 13,597.0
12/11/2023
01:45
12/11/2023
03:00
1.25 INTRM2, CEMENT CIRC P Load 2 ea 7" foam wiper balls, circ and
reciprocate 2 BU at 630 GPM, 1178 PSI,
10 RPM, 3K TQ. 6224 total stks, 153K
RTW
9,200.0 9,200.0
12/11/2023
03:00
12/11/2023
03:30
0.50 INTRM2, CEMENT OWFF P OWFF, BD TD, prep floor to LD 5-7/8"
DP
9,200.0 9,200.0
12/11/2023
03:30
12/11/2023
06:00
2.50 INTRM2, CEMENT PULD P Pump 30 bbl dry job, POOH LD 5-7/8"
DP/HWDP to shed F/ 9,200' to 8,194'.
167K PUW. Monitor hole fill on TT.
9,200.0 8,194.0
12/11/2023
06:00
12/11/2023
07:30
1.50 INTRM2, CEMENT PULD P POOH LD 5-7/8" DP/HWDP to shed F/
8,194' to 6,240'. 155K PUW. Monitor
hole fill on TT.
8,194.0 6,240.0
12/11/2023
07:30
12/11/2023
09:00
1.50 INTRM2, CEMENT TRIP P POOH w/ 5-7/8" DP, rack stds in derrick
F/ 6,240' to 3,660' MD. 141K PUW.
Monitor hole fill on TT.
6,240.0 3,660.0
12/11/2023
09:00
12/11/2023
10:15
1.25 INTRM2, CEMENT RURD P Change out TD saver sub to 4-1/2"
D425 while change hose on ST-120.
3,660.0 3,660.0
12/11/2023
10:15
12/11/2023
12:00
1.75 INTRM2, CEMENT TRIP P POOH w/ 5-7/8" DP, rack stds in derrick
F/ 3,660' to 58' MD. Monitor hole fill on
TT.
3,660.0 58.0
12/11/2023
12:00
12/11/2023
13:00
1.00 INTRM2, CEMENT RURD P LD Qril-Quip running tool. SIMOPS:
Drain stack, close rams, power down
Koomey, change upper rams to 3-1/2" x
6-5/8" VBR's,
58.0 0.0
12/11/2023
13:00
12/11/2023
14:30
1.50 INTRM2, CEMENT RURD P MU 4-1/2" test jt, pups and WR running
tool, pull wear ring and set test plug per
FMC. SIMOPS: prep for slip and cut
0.0 0.0
12/11/2023
14:30
12/11/2023
16:30
2.00 INTRM2, CEMENT SLPC P Hang blocks, remove guards, cut and
slip 70' drilling line. inspect brakes,
deadman and dog knot. Conduct full
brake test.
0.0 0.0
12/11/2023
16:30
12/11/2023
17:00
0.50 INTRM2, CEMENT RURD P Prep for BOP test. Flood surface lines,
conduct shell test.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 25/37
CD4-587
Report Printed: 1/24/2024
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)
12/11/2023
17:00
12/11/2023
23:00
6.00 INTRM2, WHDBOP BOPE P Performed BOP test with 4-1/2" & 5-
7/8" test joints and charted all test.
Annular to 250/2500 psi, 5 min each.
Remaining tests 250/3850 psi, 5 min
each.
#1 Annular with 4-1/2" test joint to 250
psi low, 2500 psi high.
#2 Upper VBRs 3-1/2" x 6-5/8" with 4-
1/2" test joint; CMV 1,14, 15, 16, kill line
valve #3.
#3 HCR kill; CMV 10, 13, needle valve
above #1.
#4 Manual kill; CMV 4, 9, 12, 4-1/2"
dart valve.
#5 CMV 6, 8, 11, 4-1/2" FOSV.
#6 CMV 5 & 7.
#7 CMV 2
#8 HCR choke valve
#9 Manual choke valve .
#10 Lower VBRs 3-1/2" x 6-5/8" with 4-
1/2" test joint
#11 Blind / shear rams; CMV 3,4,6.
#12 Manual choke & super choke to
1500 psi.
#13 Upper 3-1/2" X 6-5/8" VBRs with 5-
7/8" test joint & upper IBOP
#14 Lower 3-1/2" X 6-5/8" VBRs with 5-
7/8" test joint & lower IBOP.
Conducted accumulator draw down.
System pressure 3025 psi; manifold
pressure 1500 psi; after all closures
1700 psi; 200 psi build with 2 electric
pumps in 13 seconds; full pressure
attained in 83 seconds. Closing times:
annular 16 seconds; UPR 14 seconds;
blind/shear 14 seconds; LPR 13
seconds; choke HCR 1 second; kill HCR
1 second. 10 bottles nitrogen backup
3950 psi average. Gas detection
system, pit level indicators and flow
alarms tested. Test witness waived by
AOGCC, Brian Bixby.
0.0 0.0
12/11/2023
23:00
12/12/2023
00:00
1.00 INTRM2, DRILLOUT RURD P Blow down BOP equipment, pull test
plug, install wear ring per FMC, RU for
casing test, fill stack with mud.
0.0 0.0
12/12/2023
00:00
12/12/2023
01:30
1.50 INTRM2, DRILLOUT PRTS P Perform casing test. Close blind rams,
pump down kill line at 5 spm, Pressure
up to 3850 PSI with 102 Stks. Hold 30
minutes. Bleed off pressure, 12 bbls
returned. SIMOPS: Grease/Inspect TD.
Grease upper/Lower IBOP's
0.0 0.0
12/12/2023
01:30
12/12/2023
01:45
0.25 INTRM2, DRILLOUT RURD P Clear floor.Open blind rams. Blow down
kill line. Prep for BHA
0.0 0.0
12/12/2023
01:45
12/12/2023
05:30
3.75 INTRM2, DRILLOUT BHAH P PJSM, MU 6-1/2" Production BHA per
SLB DD/MWD T/257' MD. Monitor
displacement on TT. SIMOPS: Rebuild
and test manual choke B
0.0 257.0
12/12/2023
05:30
12/12/2023
06:00
0.50 INTRM2, DRILLOUT TRIP P RIH on 4-1/2" DP F/ 257' to 1,293' MD
with stands from derrick. Monitor
displacement on TT. 94K SOW
257.0 1,293.0
12/12/2023
06:00
12/12/2023
06:30
0.50 INTRM2, DRILLOUT TRIP P RIH on 4-1/2" DP F/ 1,293' to 2,137' MD
with stands from derrick. Monitor
displacement on TT. 106K SOW
1,293.0 2,137.0
12/12/2023
06:30
12/12/2023
07:15
0.75 INTRM2, DRILLOUT CIRC P Fill pipe, shallow hole test MWD per
MWD/DD. 240 GPM, 1360 PSI. Blow
down TD
2,137.0 2,137.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 26/37
CD4-587
Report Printed: 1/24/2024
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)
12/12/2023
07:15
12/12/2023
10:00
2.75 INTRM2, DRILLOUT TRIP P RIH on 4-1/2" DP F/ 1,293' to 2,137' MD
with stands from derrick. Monitor
displacement on TT. 106K SOW
2,137.0 9,122.0
12/12/2023
10:00
12/12/2023
10:30
0.50 INTRM2, DRILLOUT REAM P Wash/Ream F/ 9,122' to 9,225' MD. 245
GPM, 1550 PSI, 30 RPM, 3K TQ, 10%
FO, 10.21 ECD, 139K PUW, 116K
SOW, 127K RTW
9,122.0 9,225.0
12/12/2023
10:30
12/12/2023
10:45
0.25 INTRM2, DRILLOUT DRLG P Tag DPOB at 9,225' MD. Drill out per
DD, 245 GPM, 1645 PSI, 40 RPM, 5K
TQ, 10% FO, 10.23 ECD, 3-7K WOB,
ream 3X's.
9,225.0 9,226.0
12/12/2023
10:45
12/12/2023
11:00
0.25 INTRM2, DRILLOUT REAM P Wash/Ream F/ 9,226' to 9,307' MD. 245
GPM, 1650 PSI, 40 RPM, 3K TQ, 10%
FO, 10.24 ECD
9,226.0 9,307.0
12/12/2023
11:00
12/12/2023
12:00
1.00 INTRM2, DRILLOUT TRIP P RIH w/ 4-1/2" DP F/ 9,307' to 10,260'
MD. Monitor displacement on TT. 103K
SOW. Logging cement with recorded
sonic tool at 1800'/hr
9,307.0 10,260.0
12/12/2023
12:00
12/12/2023
16:00
4.00 INTRM2, DRILLOUT TRIP P RIH w/ 4-1/2" DP F/ 10,260' to 13,419'
MD. Monitor displacement on TT. 103K
SOW. Logging cement with recorded
sonic tool at 1800'/hr. Wash and ream
as needed, 245 GPM, 2020 PSI, 40
RPM, 6K TQ, 123K RTW
10,260.0 13,419.0
12/12/2023
16:00
12/12/2023
17:00
1.00 INTRM2, DRILLOUT MPDA P Tag plugs/LC at 13,419' w/ 6K WOB.
Blow down TD, PJSM, install 4-1/2"
MPD bearing/element.
13,419.0 13,419.0
12/12/2023
17:00
12/12/2023
20:30
3.50 INTRM2, DRILLOUT DISP P PJSM, displace over T/ 8.2 ppg
VersaClean mud per mud man. 7700
total stks pumped. Function MPD
chokes and ramp.
13,419.0 13,419.0
12/12/2023
20:30
12/12/2023
23:00
2.50 INTRM2, DRILLOUT DRLG P Drill plugs/Landing collar from 13,419' to
13,422' MD per DD. 250 GPM, 2164
PSI, 9.5 ECD, 60 RPM, 10-14K TQ
13,419.0 13,422.0
12/12/2023
23:00
12/13/2023
00:00
1.00 INTRM2, DRILLOUT DRLG P Drill cement F/ 13,422' to 13,457' MD.
250 GPM, 2241 PSI, 9.4 ECD, 80 RPM,
12K TQ, 140K PUW
13,422.0 13,457.0
12/13/2023
00:00
12/13/2023
01:30
1.50 INTRM2, DRILLOUT DRLG P Drill cement F/ 13,457' to 13,508' MD.
250 GPM, 2205 PSI, 9.4 ECD, 80 RPM,
12K TQ, 17K WOB, 141K PUW
13,457.0 13,508.0
12/13/2023
01:30
12/13/2023
02:30
1.00 INTRM2, DRILLOUT DRLG P Drill float collar F/ 13,508' to 13,511' MD.
250 GPM, 2180 PSI, 9.5 ECD, 80 RPM,
8-15K TQ, 30-32K WOB
13,508.0 13,511.0
12/13/2023
02:30
12/13/2023
05:30
3.00 INTRM2, DRILLOUT DRLG P Drill cement F/ 13,511' to 13,591' MD.
250 GPM, 2180 PSI, 9.4 ECD, 80 RPM,
10K TQ, 20K WOB
13,511.0 13,591.0
12/13/2023
05:30
12/13/2023
06:00
0.50 INTRM2, DRILLOUT DRLG P Drill shoe F/ 13,591' to 13,593' MD per
DD. 250 GPM, 2190 PSI, 9.5 ECD, 80
RPM, 14K TQ, 30K WOB
13,591.0 13,593.0
12/13/2023
06:00
12/13/2023
10:15
4.25 INTRM2, DRILLOUT DRLG P Drill Citadel shoe per DD F/ 13,593' to
13,596' MD. 210 GPM, 1645 PSI, 9.3
ECD, 20 RPM, 8K TQ, 10% FO, 30-60K
WOB, ream 3X's
13,593.0 13,596.0
12/13/2023
10:15
12/13/2023
10:30
0.25 INTRM2, DRILLOUT DRLG P Drill rathole F/ 13,596' to 13,599' MD.
240 GPM, 2135 PSI, 9.48 ECD, 80
RPM, 9K TQ
13,596.0 13,599.0
12/13/2023
10:30
12/13/2023
10:45
0.25 INTRM2, DRILLOUT DDRL P Drill 6-1/2" production hole F/ 13,599' to
13,619' MD, 4,070' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. 240 GPM, 2153 PSI, 9.48 ECD,
11% FO, 80 RPM, 11K TQ, 11K WOB,
177K PUW, 97K SOW, 126K RTW,
ADT=.22 Hrs, Bit =.22 Hrs
13,599.0 13,619.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 27/37
CD4-587
Report Printed: 1/24/2024
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)
12/13/2023
10:45
12/13/2023
12:45
2.00 INTRM2, DRILLOUT CIRC P Circ and reciprocate F/ 13,615' to
13,558' MD. 240 GPM, 2132 PSI, 80
RPM, 9K TQ, 10% FO, 9.52 ECD, 5700
stks total pumped
13,619.0 13,588.0
12/13/2023
12:45
12/13/2023
13:15
0.50 INTRM2, DRILLOUT FIT P Conduct FIT to 13.0 PPG EMW.
Pressure up to 1020 PSI with 23 stks,
hold 10 min, final pressure 966 PSI,
bleed back to TT, 1.7 bbl returned.
13,599.0 13,588.0
12/13/2023
13:15
12/13/2023
13:45
0.50 INTRM2, DRILLOUT FIT P RD, ream to bottom, 240 GPM, 2037
PSI, 9.56 ECD, 40 RPM, 8K TQ
13,588.0 13,619.0
12/13/2023
13:45
12/13/2023
18:00
4.25 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 13,619' to
13,836' MD, 4,094' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
250 GPM, 2240 PSI, 9.7 ECD, 9% FO,
100 RPM, 10K TQ on, 7K TQ off, 6K
WOB, 179K PUW, 97K SOW, 126K
RTW, max gas units= 35
ADT=.22 Hrs, Bit =.22 Hrs
13,619.0 13,836.0
12/13/2023
18:00
12/13/2023
19:00
1.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 13,836' to
13,930' MD, 4,094' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
250 GPM, 2240 PSI, 9.7 ECD, 9% FO,
100 RPM, 10K TQ on, 7K TQ off, 6K
WOB, 179K PUW, 97K SOW, 126K
RTW, max gas units= 35
ADT=.22 Hrs, Bit =.22 Hrs
13,836.0 13,930.0
12/13/2023
19:00
12/13/2023
19:30
0.50 PROD1, DRILL CIRC P Perform low flow ECD test.
200 GPM, 0 RPM = 9.34 ECD
200 GPM, 80 RPM = 9.4 ECD
250 GPM, 0 RPM = 9.37 ECD
250 GPM, 80 RPM = 9.5 ECD
13,930.0 13,930.0
12/13/2023
19:30
12/14/2023
00:00
4.50 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 13,836' to
14,211' MD, 4,127' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 2547 PSI, 9.9 ECD, 12% FO,
120 RPM, 12K TQ on, 7K TQ off, 11K
WOB, 182K PUW, 110K SOW, 138K
RTW, max gas units= 301
ADT=4.10 Hrs, Bit =7.24 Hrs
13,930.0 14,211.0
12/14/2023
00:00
12/14/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 14,211' to
14,781' MD, 4,781' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 2608 PSI, 10.3 ECD, 12%
FO, 120 RPM, 12K TQ on, 9K TQ off,
15K WOB, 193K PUW, 111K RTSOW,
143K RTW, max gas units= 171
ADT=4.38 Hrs, Bit =11.62 Hrs
14,211.0 14,781.0
12/14/2023
06:00
12/14/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 14,781' to
15,467' MD, 4,115' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 2616 PSI, 10.6 ECD, 13%
FO, 120 RPM, 12K TQ on, 7K TQ off,
17K WOB, 187K PUW, 108K RTSOW,
131K RTW, max gas units= 279
ADT=4.31 Hrs, Bit =15.93 Hrs
14,781.0 15,467.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 28/37
CD4-587
Report Printed: 1/24/2024
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)
12/14/2023
12:00
12/14/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 15,467' to
16,152' MD, 4,142' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 2863 PSI, 10.7 ECD, 13%
FO, 120 RPM, 11K TQ on, 8K TQ off,
19K WOB, 204K PUW, 103K RTSOW,
135K RTW, max gas units= 605
ADT=4.31 Hrs, Bit =20.24 Hrs
15,467.0 16,152.0
12/14/2023
18:00
12/15/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 16,152' to
16,854' MD, 4,146' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 2863 PSI, 10.7 ECD, 13%
FO, 120 RPM, 12K TQ on, 8K TQ off,
15K WOB, 204K PUW, 103K RTSOW,
135K RTW, max gas units= 398
ADT=4.28 Hrs, Bit =24.52 Hrs
16,152.0 16,854.0
12/15/2023
00:00
12/15/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 16,854' to
17,552' MD, 4,171' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 2902 PSI, 11.4 ECD, 13%
FO, 120 RPM, 13K TQ on, 11K TQ off,
15K WOB, 197K PUW, 110K RTSOW,
136K RTW, max gas units= 545
ADT=4.29 Hrs, Bit =28.81 Hrs
16,854.0 17,552.0
12/15/2023
06:00
12/15/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 17,552' to
18,245' MD, 4,146' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 3024 PSI, 11.7 ECD, 13%
FO, 120 RPM, 14K TQ on, 11K TQ off,
18K WOB, 204K PUW, 106K RTSOW,
137K RTW, max gas units= 360
ADT=4.31 Hrs, Bit =33.12 Hrs
17,552.0 18,245.0
12/15/2023
12:00
12/15/2023
21:00
9.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 18,245' to
19,175' MD, 4,176' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 3111 PSI, 11.8 ECD, 13%
FO, 120 RPM, 15K TQ on, 12K TQ off,
14-18K WOB, 206K PUW, 99K RTSOW,
134K RTW, max gas units= 358
ADT=5.82 Hrs, Bit =38.94 Hrs
18,245.0 19,175.0
12/15/2023
21:00
12/16/2023
00:00
3.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 19,175' to
19,513' MD, 4,187' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 3037 PSI, 11.8 ECD, 13%
FO, 120 RPM, 14K TQ on, 11K TQ off,
14K WOB, 210K PUW, 98K RTSOW,
136K RTW, max gas units= 481
ADT=2.13 Hrs, Bit =41.07 Hrs
19,175.0 19,513.0
12/16/2023
00:00
12/16/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 19,513' to
20,200' MD, 4,187' TVD. Maintain 10.0
ppg EMW at shoe on connections w/
MPD. Obtain T&D every 5th stand
270 GPM, 3075 PSI, 11.82 ECD, 12%
FO, 120 RPM, 14K TQ on, 12K TQ off,
15K WOB, 207K PUW, 98K RTSOW,
136K RTW, max gas units= 458
ADT=4.14 Hrs, Bit =45.21 Hrs
19,513.0 20,200.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 29/37
CD4-587
Report Printed: 1/24/2024
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)
12/16/2023
06:00
12/16/2023
10:15
4.25 PROD1, DRILL DDRL P Drill 6-1/2" production hole F/ 20,200' to
TD at 20,669' MD, 4,195' TVD. Maintain
10.0 ppg EMW at shoe on connections
w/ MPD. Obtain T&D every 5th stand
270 GPM, 3150 PSI, 12.0 ECD, 12%
FO, 120 RPM, 16K TQ on, 12K TQ off,
16K WOB, 210K PUW, 100K RTSOW,
136K RTW, max gas units= 403
ADT=2.97 Hrs, Bit =48.18 Hrs
20,200.0 20,669.0
12/16/2023
10:15
12/16/2023
12:00
1.75 PROD1, TRIPCAS CIRC P Circulate hole clean w/ rotate and
reciprocate and prep pits for
displacement.
270 GPM, 3020 PSI, 11.3 ECD, 120
RPM, 14K TQ, 130K RTW
20,669.0 20,623.0
12/16/2023
12:00
12/16/2023
14:30
2.50 PROD1, TRIPCAS CIRC P Circulate hole clean w/ rotate and
reciprocate and prep pits for
displacement.
270 GPM, 3020 PSI, 11.3 ECD, 120
RPM, 14K TQ, 130K RTW
20,623.0 20,535.0
12/16/2023
14:30
12/16/2023
18:00
3.50 PROD1, TRIPCAS CIRC P Std back a stand, cont circulate hole
clean w/ rotate and reciprocate and prep
pits for displacement.
270 GPM, 3020 PSI, 11.3 ECD, 120
RPM, 14K TQ, 130K RTW
20,535.0 20,535.0
12/16/2023
18:00
12/16/2023
19:00
1.00 PROD1, TRIPCAS CIRC P Cont circulate hole clean w/ rotate and
reciprocate 4X BU and prep pits for
displacement.
270 GPM, 2975 PSI, 11.16 ECD, 120
RPM, 12K TQ, 130K RTW. 26,800 total
stks pumped
20,535.0 20,535.0
12/16/2023
19:00
12/16/2023
19:45
0.75 PROD1, TRIPCAS CIRC P Perform low flow ECD test.
250 GPM, 80 RPM, 10.79 ECD
200 GPM, 80RPM, 10.32 ECD
20,535.0 20,535.0
12/16/2023
19:45
12/16/2023
23:45
4.00 PROD1, TRIPCAS DISP P Displace to 9.6 ppg KW NAF w/
Rot/Recip. 270-150 GPM, 1480 PSI.
120 RPM, 13K TQ. Keeping ECD's
below 12.0 ppg. No losses. Obtain
SPR's.
20,535.0 20,535.0
12/16/2023
23:45
12/17/2023
00:00
0.25 PROD1, TRIPCAS SMPD P Blow down TD. Prep floor for stripping
OOH
20,535.0 20,535.0
12/17/2023
00:00
12/17/2023
00:45
0.75 PROD1, TRIPCAS OWFF P OWFF, static 30 min. Fill RCD riser with
9.6 KWF
20,535.0 20,535.0
12/17/2023
00:45
12/17/2023
06:00
5.25 PROD1, TRIPCAS SMPD P Strip OOH F/ 20,465' to 16,196' MD with
MPD holding 10.0 ppg EMW at TD.
Monitor hole fill on pit #4. 200K PUW.
20,535.0 16,196.0
12/17/2023
06:00
12/17/2023
09:15
3.25 PROD1, TRIPCAS SMPD P Strip OOH F/ 16,196' to 13,551' MD with
MPD holding 10.0 ppg EMW at TD.
Monitor hole fill on pit #4. 137K PUW.
16,196.0 13,551.0
12/17/2023
09:15
12/17/2023
10:00
0.75 PROD1, TRIPCAS CIRC P Drop 1.75" SS ball, pump down to open
WellCommander. 230 GPM, 2140 PSI,
15 RPM, 5K TQ, 137K RTW. Slowed to
75 GPM, 486 PSI at 752 stks. Ball on
seat at 1026 stks. WellCommander
open at 1037 stks, 2008 PSI
13,551.0 13,551.0
12/17/2023
10:00
12/17/2023
12:00
2.00 PROD1, TRIPCAS CIRC P Circulate casing clean w/ rotate and
reciprocate. 450 GPM, 2400 PSI, 73
RPM, 7-10K TQ, 125K RTW
13,551.0 13,551.0
12/17/2023
12:00
12/17/2023
12:45
0.75 PROD1, TRIPCAS CIRC P Drop 1.75" SS ball, pump down to close
WellCommander. 230 GPM, 697 PSI, 12
RPM, 5K TQ, 135K RTW. Slowed to 75
GPM, 300 PSI at 752 stks. Ball on seat
at 1041 stks. WellCommander closed at
1055 stks, 2008 PSI
13,551.0 13,551.0
12/17/2023
12:45
12/17/2023
13:00
0.25 PROD1, TRIPCAS RURD P Blow down TD, install stripping ribbers 13,551.0 13,551.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 30/37
CD4-587
Report Printed: 1/24/2024
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)
12/17/2023
13:00
12/17/2023
18:00
5.00 PROD1, TRIPCAS SMPD P Strip OOH F/ 13,551' to 7,236' MD with
MPD holding 10.0 ppg EMW at TD.
Monitor hole fill on pit #4. 138K PUW.
13,551.0 7,236.0
12/17/2023
18:00
12/17/2023
23:30
5.50 PROD1, TRIPCAS SMPD P Strip OOH F/ 7,236' to 445' MD with
MPD holding 10.0 ppg EMW at TD.
Monitor hole fill on pit #4. 85K PUW.
7,236.0 445.0
12/17/2023
23:30
12/18/2023
00:00
0.50 PROD1, TRIPCAS OWFF P Drain RCD, OWFF 445.0 445.0
12/18/2023
00:00
12/18/2023
00:30
0.50 PROD1, TRIPCAS MPDA P Pull 4-1/2" MPD bearing/element per
MPD rep
445.0 445.0
12/18/2023
00:30
12/18/2023
01:00
0.50 PROD1, TRIPCAS TRIP P Fill riser, swap to TT, POOH F/ 445' to
257' MD. Monitor hole fill on TT. 83K
PUW
445.0 257.0
12/18/2023
01:00
12/18/2023
04:45
3.75 PROD1, TRIPCAS BHAH P PJSM, LD 6-1/2" BHA per SLB
DD/MWD. Monitor hole fill on TT.
257.0 0.0
12/18/2023
04:45
12/18/2023
06:00
1.25 PROD1, TRIPCAS RURD P Clear floor, LD all BHA equipment.
SIMOPS: Change out saver sub.
0.0 0.0
12/18/2023
06:00
12/18/2023
09:00
3.00 COMPZN, CASING RURD P Install and torque lock rings on saver
sub, Install all keepers. Clean floor of
OBM/trash. Mobilize liner equip to floor
and RU
0.0 0.0
12/18/2023
09:00
12/18/2023
12:00
3.00 COMPZN, CASING PUTB P PJSM, MU and RIH (Float) w/ 4-1/2",
12.6#, P110, H563 liner per tally to 982'
MD. MU liner to 5,600 ft/lbs tq.
0.0 982.0
12/18/2023
12:00
12/18/2023
18:00
6.00 COMPZN, CASING PUTB P PJSM, MU and RIH (Float) w/ 4-1/2",
12.6#, P110, H563 liner per tallyF/ 982'
to 5,300' MD. MU liner to 5,600 ft/lbs tq.
91K SOW
982.0 5,300.0
12/18/2023
18:00
12/18/2023
20:30
2.50 COMPZN, CASING PUTB P MU and RIH (Float) w/ 4-1/2", 12.6#,
P110, H563 liner per tallyF/ 5,300' to
7,306' MD. MU liner to 5,600 ft/lbs tq.
91K SOW
5,300.0 7,306.0
12/18/2023
20:30
12/18/2023
21:30
1.00 COMPZN, CASING PUTB P MU liner hanger assy per Baker rep.
92K PUW, 91K SOW
7,306.0 7,306.0
12/18/2023
21:30
12/19/2023
00:00
2.50 COMPZN, WELLPR RUNL P RIH w/ 4-1/2", 12.6#, P110, H563 liner
on 4-1/2" DP from derrick. Monitor
displacement on TT. 109K SOW
7,306.0 10,086.0
12/19/2023
00:00
12/19/2023
03:15
3.25 COMPZN, WELLPR RUNL P RIH w/ 4-1/2", 12.6#, P110, H563 liner
on 4-1/2" DP from derrick. F/ 10,086' to
13,906' MD. Monitor displacement on
TT. Fill DP on the fly, top off every 10
stds. Obtain parameters at shoe. 138K
PUW, 109K SOW, 119K RTW
10,086.0 13,906.0
12/19/2023
03:15
12/19/2023
06:00
2.75 COMPZN, WELLPR RUNL P RIH w/ 4-1/2", 12.6#, P110, H563 liner
on 4-1/2" DP from derrick. F/ 13,906' to
16,218' MD. Monitor displacement on
TT. Fill DP on the fly, top off every 10
stds. Rotate every 10th std, 20 RPM 1st
Jt, 30 RPM 2nd Jt, 0 RPM last Jt.
13,906.0 16,218.0
12/19/2023
06:00
12/19/2023
07:45
1.75 COMPZN, WELLPR RUNL P RIH w/ 4-1/2", 12.6#, P110, H563 liner
on 4-1/2" DP from derrick. F/ 16,218' to
17,056' MD. Monitor displacement on pit
5. Fill DP on the fly, top off every 10
stds. Rotate every 10th std, 20 RPM 1st
Jt, 30 RPM 2nd Jt, 0 RPM last Jt. 169K
PUW, 90-110K SOW, 138K SOW. 5-6K
TQ at 20-30 RPM
16,218.0 17,056.0
12/19/2023
07:45
12/19/2023
12:00
4.25 COMPZN, WELLPR RUNL P RIH w/ 4-1/2", 12.6#, P110, H563 liner
on 4-1/2" DP from derrick. F/ 17,056' to
18,904' MD. Rotate down every stand at
20 RPM, 7-8K TQ. Monitor
displacement on pit 5. Fill DP on the fly,
top off every 5 stds. 188K PUW, 120K
SOW, 137K SOW. 7-8K TQ at 20-30
RPM
17,056.0 18,904.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 31/37
CD4-587
Report Printed: 1/24/2024
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)
12/19/2023
12:00
12/19/2023
17:15
5.25 COMPZN, WELLPR RUNL P RIH w/ 4-1/2", 12.6#, P110, H563 liner
on 4-1/2" DP from derrick. F/ 18,904' to
20,494' MD. Rotate down every stand at
20 RPM, 9-10K TQ. Monitor
displacement on pit 5. Fill DP on the fly,
top off every 5 stds. 190K PUW, 118K
SOW, 150K SOW. 9-10K TQ at 20 RPM
18,904.0 20,492.0
12/19/2023
17:15
12/19/2023
17:45
0.50 COMPZN, WELLPR RUNL T At 20,492', Tq up to 14K and stall w/
20K drag down. Release Tq, PU to
250K, no break over. Inc Tq to 20K,
attempt to rot down 3X, stalling.
20,492.0 20,492.0
12/19/2023
17:45
12/19/2023
18:00
0.25 COMPZN, WELLPR RUNL T LD Bottom single of std #142. MU Dbl to
TD
20,492.0 20,492.0
12/19/2023
18:00
12/19/2023
20:15
2.25 COMPZN, WELLPR RUNL T Cont to work liner attempt to free. Max
PU wt of 380K, worked 10K torque
down. No success, consult town,
decision made to proceed with setting
liner where its at, 152' from planned
setting depth. RU vent assembly, 9'
Pup, TIW, SES, 9' pup and hose.
20,492.0 20,492.0
12/19/2023
20:15
12/19/2023
22:00
1.75 COMPZN, WELLPR PACK P Set hanger per Baker Rep. PU to 220K,
pressure up to 3000 psi for 5 min, SO to
85K verify no movement, Bleed off
pressure, line up to pump down
backside, close upper VBR, pressure up
to 3850 psi for 10 min, bleed off
pressure, open rams. Pump down DP to
3600 psi for 10 min to hyd release
running tool. Pressure up to 4300 psi to
rupture Arsenal shear sub, no go, bleed
pressure and try again, pressured up to
4375 psi and sheared sub.
20,492.0 20,492.0
12/19/2023
22:00
12/19/2023
22:30
0.50 COMPZN, WELLPR CIRC P Fill liner and vent with 107 bbls 9.6 ppg
NAF at 10 bpm. RD vent assy.
20,492.0 20,492.0
12/19/2023
22:30
12/19/2023
23:00
0.50 COMPZN, WELLPR PACK P PU and confirm released with 190K
PUW, cont PU 6' expose dog sub, SO
and set 10K down on dogs. Confirm
TOL at 13,200' MD. PU 32' to place RT
at TOL.
20,492.0 13,200.0
12/19/2023
23:00
12/20/2023
00:00
1.00 COMPZN, WELLPR DISP P PJSM, displace well from 9.6 ppg NAF
to 9.6 ppg CI KW brine.
13,200.0 13,200.0
12/20/2023
00:00
12/20/2023
02:30
2.50 COMPZN, WELLPR DISP P Displace Well to 9.6 ppg KCL Brine
GPM = 325 PSI = 638 Total STKS
pumped 9900.
13,200.0 13,200.0
12/20/2023
02:30
12/20/2023
03:30
1.00 COMPZN, WELLPR OWFF P Blow down top drive and perform open
well flow check. Prep floor for POOH,
L/D singles.
13,200.0 13,200.0
12/20/2023
03:30
12/20/2023
06:00
2.50 COMPZN, WELLPR PULD P POOH with 5-7/8" drill pipe laying
singles down to pipeshed. Monitor well
via trip tank.
13,200.0 10,350.0
12/20/2023
06:00
12/20/2023
07:00
1.00 COMPZN, WELLPR OWFF P Perform flow check blow down top drive
and prep floor for POOH.
10,350.0 10,350.0
12/20/2023
07:00
12/20/2023
11:30
4.50 COMPZN, WELLPR PULD P POOH with 5-7/8" drill pipe laying
singles down to pipeshed. Monitor well
via trip tank.
10,350.0 6,557.0
12/20/2023
11:30
12/20/2023
12:00
0.50 COMPZN, WELLPR RURD P Change out 5-7/8" handling equipment
to 4-1/2".
6,557.0 6,557.0
12/20/2023
12:00
12/20/2023
18:00
6.00 COMPZN, WELLPR PULD P POOH laying down 4-1/2" singles to
pipe shed.
6,557.0 51.0
12/20/2023
18:00
12/20/2023
19:00
1.00 COMPZN, WELLPR BHAH P L/D Baker liner running tools no
indication of damage or malfunction.
51.0 0.0
12/20/2023
19:00
12/20/2023
19:30
0.50 COMPZN, WELLPR BHAH P Clean and clear rig floor R/U to RIH with
4-1/2" pipe from derrick.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 32/37
CD4-587
Report Printed: 1/24/2024
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)
12/20/2023
19:30
12/21/2023
00:00
4.50 COMPZN, WELLPR TRIP P RIH with 4-1/2" drillpipe from derrick for
laying down.
0.0 11,626.0
12/21/2023
00:00
12/21/2023
00:30
0.50 COMPZN, WELLPR TRIP P RIH with 4-1/2" drillpipe from derrick
from 11,626' to 12,759'.
PUW 160K
SOW 110K
Monitor displacement via trip tank.
11,626.0 12,759.0
12/21/2023
00:30
12/21/2023
01:00
0.50 COMPZN, WELLPR SVRG P Service rig, top drive, ST-120 and pipe
skate.
12,759.0 12,759.0
12/21/2023
01:00
12/21/2023
01:30
0.50 COMPZN, WELLPR RURD P Prepare rig floor to L/D 4.5" drill pipe. 12,759.0 12,759.0
12/21/2023
01:30
12/21/2023
06:45
5.25 COMPZN, WELLPR PULD P POOH laying down singles of 4.5" drill
pipe from 12,759' to 6,915'
PUW 130K
Monitor hole displacement via trip tank.
12,759.0 6,915.0
12/21/2023
06:45
12/21/2023
07:45
1.00 COMPZN, WELLPR TRIP P Pull stripping rubber and RIH from
6,915' to 7,315' remaining stands from
derrick.
6,915.0 7,315.0
12/21/2023
07:45
12/21/2023
12:00
4.25 COMPZN, WELLPR PULD P POOH laying down singles of 4.5" drill
pipe from 7,315' to 3,020'
PUW 116K
Monitor hole displacement via trip tank.
7,315.0 3,020.0
12/21/2023
12:00
12/21/2023
14:00
2.00 COMPZN, WELLPR PULD P POOH laying down singles of 4.5" drill
pipe from 3,020' to 1,050'
PUW 90K
Monitor hole displacement via trip tank.
3,020.0 1,050.0
12/21/2023
14:00
12/21/2023
14:30
0.50 COMPZN, WELLPR RURD P Mobilize control line spool, spooler and
clamps to rig floor.
1,050.0 1,050.0
12/21/2023
14:30
12/21/2023
16:00
1.50 COMPZN, WELLPR PULD P POOH laying down singles of 4.5" drill
pipe from 1050' to 0'
Monitor hole displacement via trip tank.
1,050.0 0.0
12/21/2023
16:00
12/21/2023
18:00
2.00 COMPZN, RPCOMP RURD P C/O elevators pick up 2 joints of 5-7/8"
and make up stack washer. Stage in
mouse hole P/U wear ring puller and
make up to 5" pipe and pull wear ring as
per FMC rep. L/D wear ring puller and 2
joints of drill pipe.
0.0 0.0
12/21/2023
18:00
12/21/2023
19:15
1.25 COMPZN, RPCOMP WWWH P P/U stack washer and wash stack. 0.0 0.0
12/21/2023
19:15
12/21/2023
22:30
3.25 COMPZN, RPCOMP RURD P Rig up Silverwell mandrel spool and
connect TEC wire, R/U sheave in
derrick.
0.0 0.0
12/21/2023
22:30
12/22/2023
00:00
1.50 COMPZN, RPCOMP PUTB P PJSM and M/U HES self orientating
mule shoe and RIH with 4-1/2", 12.6#
HYD 563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
0.0 566.0
12/22/2023
00:00
12/22/2023
03:00
3.00 COMPZN, RPCOMP PUTB P RIH with 4-1/2", 12.6# HYD 563 upper
completions as per tally. Make up to
3800# fill on the fly and top off every 10
joints. Monitor hole displacement via pit
#4.
566.0 3,676.0
12/22/2023
03:00
12/22/2023
07:45
4.75 COMPZN, RPCOMP OTHR P Make up SilverWell smart GLM and
DHG as per SilverWell reps. Test
connections.
3,676.0 3,676.0
12/22/2023
07:45
12/22/2023
08:15
0.50 COMPZN, RPCOMP OTHR P Remove TEC line from mandrel and set
in mouse hole.
3,676.0 3,676.0
12/22/2023
08:15
12/22/2023
09:00
0.75 COMPZN, RPCOMP PUTB P Continue in hole with 4-1/2", 12.6# HYD
563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
3,676.0 4,169.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 33/37
CD4-587
Report Printed: 1/24/2024
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)
12/22/2023
09:00
12/22/2023
14:00
5.00 COMPZN, RPCOMP OTHR P P/U SilverWell mandrel from mouse
hole and Install TEC line and function
test .
4,169.0 4,169.0
12/22/2023
14:00
12/22/2023
18:00
4.00 COMPZN, RPCOMP PUTB P Continue in hole with 4-1/2", 12.6# HYD
563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
4,169.0 5,955.0
12/22/2023
18:00
12/22/2023
18:30
0.50 COMPZN, RPCOMP PUTB P Continue in hole with 4-1/2", 12.6# HYD
563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
5,955.0 6,333.0
12/22/2023
18:30
12/23/2023
00:00
5.50 COMPZN, RPCOMP PULL T SilverWell TEC wire pinched by setting
slips, decision made with town
engineers to pull tubing to Smart
mandrel and reconnect at the tool.
POOH laying down singles of 4-1/2",
12.6# HYD 563 upper completions,
inspecting each connection on the way
out. Monitor hole fill via pit #4.
6,333.0 4,095.0
12/23/2023
00:00
12/23/2023
03:45
3.75 COMPZN, RPCOMP OTHR T Disconnect damaged TEC wire from
Mandrel and Complete new connection
and required function testing on the
SilverWell Smart GLM/DHG.
4,095.0 4,095.0
12/23/2023
03:45
12/23/2023
06:00
2.25 COMPZN, RPCOMP PUTB T Continue in hole with 4-1/2", 12.6# HYD
563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
4,095.0 5,467.0
12/23/2023
06:00
12/23/2023
07:09
1.15 COMPZN, RPCOMP PUTB T Continue in hole with 4-1/2", 12.6# HYD
563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
5,467.0 6,298.0
12/23/2023
07:09
12/23/2023
12:00
4.85 COMPZN, RPCOMP PUTB P Back at depth where control line was
pinched resume planned time. Continue
in hole with 4-1/2", 12.6# HYD 563
upper completions as per tally. Make up
to 3800# fill on the fly and top off every
10 joints. Monitor hole displacement via
pit #4.
6,298.0 9,550.0
12/23/2023
12:00
12/23/2023
18:00
6.00 COMPZN, RPCOMP PUTB P Continue in hole with 4-1/2", 12.6# HYD
563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
9,550.0 12,490.0
12/23/2023
18:00
12/23/2023
19:00
1.00 COMPZN, RPCOMP PUTB P Continue in hole with 4-1/2", 12.6# HYD
563 upper completions as per tally.
Make up to 3800# fill on the fly and top
off every 10 joints. Monitor hole
displacement via pit #4.
12,490.0 13,153.0
12/23/2023
19:00
12/23/2023
19:30
0.50 COMPZN, RPCOMP HOSO P Slow RIH from 13,153 to 13,209'
locating joints as per Baker rep,
Observe shearing entering liner top and
set down 20K over on NOGO. Pick up
and verify measurement for space out 3
times.
13,153.0 13,209.0
12/23/2023
19:30
12/23/2023
21:00
1.50 COMPZN, RPCOMP THGR P L/D locating joints #315 and #316 M/U
hanger assembly and landing joint,
Terminate TEC wire through hanger as
per SilverWell Rep.
13,209.0 13,153.0
12/23/2023
21:00
12/23/2023
21:30
0.50 COMPZN, RPCOMP THGR P Drain BOP stack RIH and land hanger
on depth at 13206 MD 3.05' feet from
fully located. Run in lock down screws
as per FMC rep.
13,153.0 13,206.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 34/37
CD4-587
Report Printed: 1/24/2024
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)
12/23/2023
21:30
12/23/2023
22:00
0.50 COMPZN, RPCOMP RURD P Flood stack close upper pipe rams and
line up for pressure test. liner hanger
seals.
0.0 0.0
12/23/2023
22:00
12/23/2023
22:30
0.50 COMPZN, RPCOMP THGR P Pressure test hanger seal to 250 low for
5 minutes and 4000 psi high for 10
minutes charted on Totco BOP test #1
channel.
0.0 0.0
12/23/2023
22:30
12/24/2023
00:00
1.50 COMPZN, RPCOMP RURD P Rig down all liner handling equipment
and TEC wire spooling unit clean and
clear rig floor.
R/U for setting packer and testing
tubing.
0.0 0.0
12/24/2023
00:00
12/24/2023
00:30
0.50 COMPZN, RPCOMP PACK P Set TNT packer as per HES rep,
pressure up tubing to 3500 psi and hold
for 30 minutes.
0.0 0.0
12/24/2023
00:30
12/24/2023
02:30
2.00 COMPZN, RPCOMP PRTS T Bleed down tubing to 2500 psi and
pressure up IA for tubing hanger test to
3850 psi and observe communication
with tubing, Bleed down tubing to 2500
psi and IA is still transferring pressure to
tubing side. Check all surface
equipment and line up tubing and IA on
separate pumps and retry test.
Communication between IA and tubing
still noted. Bled off IA to zero and note
tubing holding pressure indicating
communication is only from IA to tubing
and not from tubing to IA.
Vendor NPT SilverWell
0.0 0.0
12/24/2023
02:30
12/24/2023
03:30
1.00 COMPZN, RPCOMP WAIT T Standby on rig while problem is
discussed with superintendent and
completions engineer.
Rig clean pits and make preparations for
rig move while waiting.
Vendor NPT SilverWell
0.0 0.0
12/24/2023
03:30
12/24/2023
04:15
0.75 COMPZN, RPCOMP PRTS T Perform various tests at varying
pressures on tubing and IA to help
identify the potential source of leak.
Vendor NPT SilverWell
0.0 0.0
12/24/2023
04:15
12/24/2023
07:30
3.25 COMPZN, RPCOMP WAIT T Evaluate test results with engineers and
develop a plan forward that will allow us
to nipple down BOPs and conduct
flushing and function testing of the
SilverWell GLM/DHG.
Continue offline rig work , Pit cleaning,
work on MP2 work orders, rig house
keeping. Change discharge filters on
sub HPU. Begin flushing pit Mod
centrifugal pumps with Deep Clean.
Vendor NPT SilverWell
0.0 0.0
12/24/2023
07:30
12/24/2023
08:30
1.00 COMPZN, RPCOMP PRTS T Pressure up on tubing and IA
simultaneously to 2500 psi shut in and
hold for 15 minutes to test tubing
hanger.
Shut in tubing and increase IA pressure
to 3500 psi and note tubing pressure
increase to 3080 psi.
Shut in IA. Tubing and IA equalized at
3440 after 10 minutes.
Vendor NPT SilverWell
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 35/37
CD4-587
Report Printed: 1/24/2024
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)
12/24/2023
08:30
12/24/2023
11:30
3.00 COMPZN, RPCOMP WAIT T Provide new test results to regulating
bodies and await approval to begin
nipple down BOP.
Continue offline rig work , Pit cleaning,
work on MP2 work orders, rig house
keeping. Change discharge filters on
sub HPU. Begin flushing pit Mod
centrifugal pumps with Deep Clean.
Vendor NPT SilverWell
0.0 0.0
12/24/2023
11:30
12/24/2023
12:45
1.25 COMPZN, RPCOMP RURD P R/D test hoses and related equipment
from tubing and IA. Pull landing joint and
store in mouse hole.
0.0 0.0
12/24/2023
12:45
12/24/2023
13:15
0.50 COMPZN, RPCOMP MPSP P Install HP-BPV with tee bar as per FMC. 0.0 0.0
12/24/2023
13:15
12/24/2023
15:45
2.50 COMPZN, RPCOMP RURD P Drain brine from BOP stack and fill stack
with Safekleen and water, Flush and
blow down hole fill and jet line to riser,
blow down choke manifold.
0.0 0.0
12/24/2023
15:45
12/24/2023
16:15
0.50 COMPZN, RPCOMP RURD P Flush MPD equipment with Safekleen
and blow . Empty Safekleen and H20
out of stack.
0.0 0.0
12/24/2023
16:15
12/24/2023
18:30
2.25 COMPZN, RPCOMP RURD P L/D landing joint and pup. Pull mouse
hole and stand back in derrick, pull
master bushings and clean top of riser
bleed off koomey unit and shut down.
Clean inside flow box while nipple down
MPD flow lines.
0.0 0.0
12/24/2023
18:30
12/24/2023
20:00
1.50 COMPZN, WHDBOP NUND P Nipple down BOP stack, rack back on
storage stump and secure. Nipple down
high pressure riser and rack back in
BOP deck and secure with transport
clamp.
0.0 0.0
12/24/2023
20:00
12/24/2023
21:00
1.00 COMPZN, WHDBOP RURD P Clean and inspect top of tubing hanger,
Install test dart in HP BPV as per FMC
rep, nipple up tree adapter Run TEC
wire thru adapter flange test and
connect SilverWell TEC wire.
0.0 0.0
12/24/2023
21:00
12/24/2023
22:30
1.50 COMPZN, WHDBOP NUND P Install tree adapter, orient and stab 10k
frac tree as per FMC rep, torque all
flanges.
0.0 0.0
12/24/2023
22:30
12/25/2023
00:00
1.50 COMPZN, WHDBOP RURD P Connect TEC wire to SilverWell control
panel as per SilverWell reps.
SIMOPS: Rig up to test Frac tree.
0.0 0.0
12/25/2023
00:00
12/25/2023
02:00
2.00 COMPZN, WHDBOP PRTS P Fill frac tree with water, Perform
pressure test on 10k frac tree, 250 low
psi and 10,000 psi high, test pump leak
at high pressure bleed down and make
repairs, pressure test again 250 low and
10,000 psi high for 15 minutes each.
good test, bleed down and drain tree.
0.0 0.0
12/25/2023
02:00
12/25/2023
03:15
1.25 COMPZN, WHDBOP OTHR T Conduct cycling of Silverwell mandrel
while wait on FMC rep to return and pull
the BPV.
Vendor NPT SilverWell
0.0 0.0
12/25/2023
03:15
12/25/2023
03:45
0.50 COMPZN, WHDBOP MPSP P Remove tree cap and pull dart and test
plug as per FMC rep.
0.0 0.0
12/25/2023
03:45
12/25/2023
05:00
1.25 COMPZN, WHDBOP SEQP T Install pump in tree cap and circulation
hose . hold PJSM with Silverwell on
valve flushing procedure. Flood lines
and pressure test to 250 low and 4000
psi high.
Vendor NPT SilverWell
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 36/37
CD4-587
Report Printed: 1/24/2024
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)
12/25/2023
05:00
12/25/2023
06:00
1.00 COMPZN, WHDBOP PRTS T Pressure up tubing to 500 psi and @ 3
spm , then pump down IA until 500 psi
differentail is reached between IA and
tubing,
1275 psi IA
775 psi tubing
Isolate rig pump and monitor pressure,
note pressure stabilizes indacating there
is no longer communication between
tubing and IA.
Vendor NPT SilverWell
0.0 0.0
12/25/2023
06:00
12/25/2023
07:00
1.00 COMPZN, WHDBOP PRTS T Increase tubing pressure to 2500 psi
and shut in. Increase IA pressure to
3850 psi, tubing increase to 3050 and
stabilize, hold 3850 on IA for 30 minutes
good IA test.
Bled IA pressure to 3500 psi and dump
tubing pressure to 0 psi shearing the
SOV.
0.0 0.0
12/25/2023
07:00
12/25/2023
07:30
0.50 COMPZN, WHDBOP CIRC P Reverse circulate at 74 GPM to verify
SOV has sheared.
0.0 0.0
12/25/2023
07:30
12/25/2023
10:00
2.50 COMPZN, WHDBOP RURD P R/D and clean tubing running
equipment. Mobilize off rig floor.
Remove and L/D both rat holes.
Blow down pumps and flush with
DeepClean. Blow down mud lines.
Flush centrifugal pumps.
0.0 0.0
12/25/2023
10:00
12/25/2023
13:00
3.00 COMPZN, WHDBOP RURD P Rig up on tree for freeze protect and U-
tube.
0.0 0.0
12/25/2023
13:00
12/25/2023
16:45
3.75 COMPZN, WHDBOP FRZP P PJSM Freeze protect IA and tubing as
per section plan. Pump 103 BBLS of
diesel @ 1.25 BBL/MIN, ICP = 300 psi,
FCP = 530 PSI. U-tube diesel for 120
minutes final psi = 164.
Freeze protect depth of 1463' MD.
0.0 0.0
12/25/2023
16:45
12/25/2023
18:00
1.25 COMPZN, WHDBOP RURD P Bleed of final pressure and suck all lines
dry with dirty hydrocarbon tuck. R/D U-
tube piping.
0.0 0.0
12/25/2023
18:00
12/26/2023
00:00
6.00 DEMOB, MOVE RURD P Pull master bushings and rig floor hatch
covers, install plug in rotary table, inflate
air boots, scrub and pressure wash
inside rig floor hatches, blow down rig
floor drain lines, clean rig floor drip pan /
flow box. Offload brine f/ mud pits
continue cleaning in pits.
0.0 0.0
12/26/2023
00:00
12/26/2023
06:00
6.00 DEMOB, MOVE RURD P Continue cleaning and organizing in
mud pump room, BOP deck and
pipeshed. Scrubbing and pressure
washing Derrick A legs/ top drive rails.
Clean ceilings in pit mod, flush suction
headers.
0.0 0.0
12/26/2023
06:00
12/26/2023
12:00
6.00 DEMOB, MOVE RURD P Clean and pressure wash derrick legs
and top drive rails.
Pressure washing skate shute.
Cleaning centrifuge room and bulk
hopper room and flow line magnet room.
0.0 0.0
12/26/2023
12:00
12/26/2023
18:00
6.00 DEMOB, MOVE RURD P Clean and pressure wash derrick legs
and top drive rails.
Pressure washing skate chute.
Cleaning centrifuge room and bulk
hopper room and flow line magnet room.
Scrubbing and pressure washing blocks.
Cleaning pipeshed.
Dig out mouse hole and cut and cap
mouse hole.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 37/37
CD4-587
Report Printed: 1/24/2024
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)
12/26/2023
18:00
12/27/2023
00:00
6.00 DEMOB, MOVE RURD P Clean and pressure wash derrick legs
and top drive rails.
Pressure washing skate chute.
Cleaning centrifuge room and bulk
hopper room and flow line magnet room.
Scrubbing and pressure washing blocks.
0.0 0.0
12/27/2023
00:00
12/27/2023
06:00
6.00 DEMOB, MOVE RURD P Continue cleaning pits: scrubbing and
pressure wash shakers and piping.
Continue cleaning under gratings and
walkway in pipeshed.
Scrub and pressure wash ODS derrick
leg.
Scrub and pressure wash ST-120.
Scrape out and pressure wash rotary
table drip pan.
0.0 0.0
12/27/2023
06:00
12/27/2023
12:00
6.00 DEMOB, MOVE RURD P Continue cleaning in pits: Scrubbing and
pressure washing shakers and piping.
Continue cleaning under grating and
walkways in the pipeshed.
Continue Scrape out and pressure wash
rotary table drip pan.
0.0 0.0
12/27/2023
12:00
12/27/2023
18:00
6.00 DEMOB, MOVE RURD P Continue cleaning in pits: Scrubbing and
pressure washing shakers and piping.
Continue cleaning under grating and
walkways in the pipeshed.
Continue Scrape out and pressure wash
rotary table drip pan.
Clean top drive and RLA.
Install floor plates in cellar.
0.0 0.0
12/27/2023
18:00
12/28/2023
00:00
6.00 DEMOB, MOVE RURD P Continue cleaning in pits: Scrubbing and
pressure washing shakers and piping.
Continue cleaning under grating and
walkways in the pipeshed.
Continue Scrape out and pressure wash
rotary table drip pan.
Clean top drive and RLA.
Install floor plates in cellar.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 12/28/2023
Page 1/1
CD4-587
Report Printed: 1/24/2024
Cement Detail Report
Cement Details
Description
Surface String Cement
Cementing Start Date
11/25/2023 12:00
Cementing End Date
11/25/2023 17:15
Wellbore Name
CD4-587
Comment
Full returns during job. Bumped plug as per calculation. Floats held. Cement back to surface.
Cement Stages
Stage # 1
Description
Stage Cementing
Objective Top Depth (ftKB)
54.6
Bottom Depth (ftKB)
2,864.6
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…P Pump Final (psi)
543.0
P Plug Bump (psi)
1,100.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
12 1/4
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
54.6
Est Btm (ftKB)
2,364.0
Amount (sacks)
1,202
Class
G
Volume Pumped (bbl)
409.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sa…
6.81
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,364.0
Est Btm (ftKB)
2,864.6
Amount (sacks)
353
Class
G
Volume Pumped (bbl)
73.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sa…
5.12
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Spacer
Fluid Description Estimated Top (ftKB)
2,364.0
Est Btm (ftKB)
2,364.0
Amount (sacks) Class
*NOT IN LIBRARY
Volume Pumped (bbl)
100.0
Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal)
10.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Surface String Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 11/19/…
Page 1/1
CD4-587
Report Printed: 1/24/2024
Cement Detail Report
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
12/2/2023 23:30
Cementing End Date
12/3/2023 03:15
Wellbore Name
CD4-587
Comment
Lined up on cementers & pressure tested lines to 4000 psi. Mix & pump 73.1 bbls of 12.00 ppg Mud Push II at 4 bpm; 272 psi. Loaded bottom plug. SLB pumped
165.1 bbls of 15.8 ppg G cement at 5.5 bpm; 350-210 psi. Loaded top plug. SLB pumped 20 bbls of fresh water at 5.5 bpm, 122-64 psi. Swapped over to the rig
pump and chased cement with 10.8 ppg mud at 6 bpm, 248-670 psi. Observed bottom land & burst with 508 bbls pumped. Observed top plug bump with 672.8
bbls pumped. Pressured up to 1100 psi & held for 5 minutes. Checked floats, good. Observed minor losses with ~498 bbls pumped. Total losses during
displacement 30 bbls. CIP 02:53 hrs.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
7,329.0
Bottom Depth (ftKB)
9,361.0
Full Return?
No
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
6
P Pump Final (psi)
226.0
P Plug Bump (psi)
552.0
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)
7,329.0
Est Btm (ftKB)
9,361.0
Amount (sacks)
800
Class
G
Volume Pumped (bbl)
165.1
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sa…
4.77
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
109.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Intermediate String 1 Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 11/19/…
Page 1/1
CD4-587
Report Printed: 1/24/2024
Cement Detail Report
Cement Details
Description
Intermediate String 2 Cement
Cementing Start Date
12/10/2023 21:00
Cementing End Date
12/10/2023 23:46
Wellbore Name
CD4-587
Comment
PJSM on cementing, Line up to SLB, pump 5 bbls H20. PT to 6500 psi, SLB pump 40 bbls 12.0 ppg mud push, break head pin, load bottom dart, SLB pump 131
bbls 15.8 ppg G cement, break head pin, load top dart, SLB pump 20 bbls H2O, take over with rig pump. Rig displace with 9.3+ ppg mud at 6 bpm. PU Btm LWP
at 555 stks with 667 psi to shear at 3 bpm, continue displace at 6 bpm, at 1483 stks break head pin and load Bozo plug, continue displace at 6 bpm, PU top LWP
at 1668 stks with 1702 psi to shear at 4.3 bpm, continue displace at 6 bpm, shear btm LWP at LC at 2188 stks with 2421 psi at 2.7 bpm, continue displace at 6
bpm, slow to 5 bpm at 2527 stks, 4.0 bpm at 2780 stks, 3.0 bpm at 3201 stks, bump plug at 3303 stks, increase pressure to 500 psi over final displacement
pressure to 1448 psi for 5 min, bleed off and check floats ok.Full returns. No losses to formation. CIP at 2346 hrs.
Cement Stages
Stage # 1
Description
Intermediate String 2
Cement
Objective Top Depth (ftKB)
10,504.0
Bottom Depth (ftKB)
13,597.4
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
5
P Pump Final (psi)
950.0
P Plug Bump (psi)
1,450.0
Recip?
Yes
Stroke (ft)
12.00
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
Tail Cement
Fluid Description Estimated Top (ftKB)
10,504.0
Est Btm (ftKB)
13,597.4
Amount (sacks)
630
Class
G
Volume Pumped (bbl)
131.0
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sa…
4.76
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr)
5.92
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Intermediate String 2 Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 11/19/…
�c� 3 —bq�
SAMPLE TRANSMITTAL
TO: AOGCC
333 WEST 7TH SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
CD4-587
13680-20699
3 Boxes
SENT BY: M. McCRACKEN
l 8 -�o
DATE: January 18, 2024
AIR BILL: N/A
CPAI: CPA12024011801
CHARGE CODE: NIA
NAME: CD4-587
NUMBER OF BOXES: 3 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
� u
c�c )cc
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?CD4-587
Yes No
9. Property Designation (Lease Number):10. Field:
Colville Delta Narwhal Undefined Oil
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
20669 4195 20669 4195 1550 None None
Casing Collapse
Structural
Conductor
Surface 2260
Intermediate 1 5090
Intermediate 2 4790, 11080
Liner 9210
Packers and SSSV Type:Packers 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:Completion Engineer
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
6-Jan-24
2049211285
4-1/2"
4195
Halliburton TNT Packer, Baker SLZXP Liner
Top Packer
Perforation Depth MD (ft):
L-80
LTP @ 13211' MD/4024' TVD, Production
Packer @ 13070' MD/4006' TVD
9-5/8"9355
2864
9355
None
4390
4-1/2"
None
7-5/8"
Perforation Depth TVD (ft):
3453
133
2864
406713597
20" x 34"
13-3/8"
133
13206
6890, 12620
MD
8150
5020
Tubing MD (ft):
133
2397
Length Size
Proposed Pools:
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL384211, ADL380081, ADL391587
223-098
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20867-00-00
ConocoPhillips Alaska Inc.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
11590
Tubing Grade:
Baskoro Tejo
Baskoro.Tejo@cop.com
907-265-6462
Subsequent Form Required:
Suspension Expiration Date:
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.
m
n
P
2
6
5
6
t
_
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Dec 27, 2023
Completion Engi
By Grace Christianson at 8:04 am, Dec 28, 2023
323-687
VTL 1/2/2024
CDW 01/08/2024
Fracture Stimulate
VTL 01/09/2024
X
1/10/2024
SFD 1/8/2024
10-404
CDW 01/08/2024
*&:JLC 1/10/2024
Brett W. Huber, Sr.Digitally signed by Brett W. Huber,
Sr.
Date: 2024.01.10 09:25:50 -09'00'01/10/24
RBDMS JSB 011124
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).
Dennise Arzola
Senior Land Negotiator
Land & Business Development
PO Box 100360
Anchorage, AK 99510-0360
Office: 907-265-6297
Fax: 907-263-4966
dennise.arzola@cop.com
December 27, 2023
To: Operator and Owners (shown on Exhibit 2)
RE: Notice of Operations pursuant to 20 AAC 25.283 (a)(1) for CD4-587 Well
ADL-384211, ADL-380081, ADL-380082, and ADL-391587
Colville River Unit Agreement
Agreement No. 203488
ConocoPhillips Alaska, Inc. (“CPAI”) as Operator and on behalf of the Colville River Unit working interest
owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by
hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 (“Application”) for the CD4-587 Well (the
“Well”). The Application will be filed with the Alaska Oil and Gas Conservation Commission (“AOGCC”) on or
about December 27, 2023. This Notice is being provided pursuant to subsection of 20 AAC 25.283.
The Well is currently planned to be drilled as a directional horizontal well on leases ADL-384211, ADL-380081,
ADL-380082, and ADL-391587, as depicted on Exhibit 1, and has locations as follows:
Location FNL FEL Township Range Section Meridian
Surface 2,818.5’4,779.5’T11N R5E 19 Umiat
Top Open Interval 574’4,031’T11N R5E 28 Umiat
Bottomhole 1,189.5’555.5’T11N R5E 33 Umiat
Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current
proposed trajectory of the Well (“Notification Area”), which includes the reservoir section. Exhibit 2 is a list of
the names and addresses of all owners, landowners, surface owners, and operators of record of all properties
within the Notification Area.
Upon your request, CPAI will provide a complete copy of the Application. If you require any additional
information, please contact the undersigned.
Regards,
Enclosures: Exhibits 1 & 2
Via Certified Mail
Notice of Operations pursuant to 20 AAC 25.283 (a)(1) for CD4-587 Well
December 27, 2023
Exhibit 1
Notice of Operations pursuant to 20 AAC 25.283 (a)(1) for CD4-587 Well
December 27, 2023
Exhibit 2
List of the names and addresses of all owners, landowners, surface owners, and operators of record of all
properties within the Notification Area.
Operator & Owner:
ConocoPhillips Alaska, Inc.
700 G Street, Suite ATO-608 (Zip 99501)
PO Box 100360
Anchorage, AK 99510-0360
Attn: Ian Ramshaw, Western North Slope Asset Development Manager
Other Operators of Record:
Oil Search (Alaska), LLC
PO Box 240927
Anchorage, AK 99524
Attn: Land Manager
Landowners:
State of Alaska
Department of Natural Resources
Division of Oil and Gas
550 West 7th Avenue, Suite 1100
Anchorage, AK 99501-3560
Attention: Derek Nottingham, Director
Arctic Slope Regional Corporation
3900 C Street, Suite 801
Anchorage, AK 99503-5963
Attn: Erik Kenning, Sr. Director of Lands & Natural Resources
Surface Owner:
Kuukpik Corporation
PO Box 89187
Nuiqsut, AK 99789-0187
Attn: Joseph Nukapigak Sr., President
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)
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.
13,809' MD / 4,014; TVD per
Section 9, below. 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 11/25/2023 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
1100 psi and the floats were checked and they held.
9 & 5/8” casing cement pump report on 12/03/2023 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 1100 psi and the
floats were checked and they held.
The 7 & 5/8” casing cement report on 12/10/2023 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 1448 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.
Nanushuk reservoir is isolated by cement. SFD
See cementing operations reports for details. SFD
SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO
PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE
WELL 20 AAC 25.283(a)(7)
On 11/27/2023 the 13-3/8” casing was pressure tested to 2,600 psi for 30 minutes
On 12/03/2023 the 9-5/8” casing was pressure tested to 3,892 psi for 30 minutes.
On 12/12/2023 the 7-5/8” casing was pressure tested to 3,850 psi for 30 minutes.
On 12/24/2023 the 4-1/2” tubing was pressure tested to 3,500 psi for 30 minutes.
On 12/25/2023 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 3,125
Electronic PRV 7,125
Highest pump trip 6,625
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 200’ TVD thick at the heel of the lateral,
thickening to >1000’ 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 13808.8’ MD, -4018.0’ 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, 2996.8’ MD, -2383.5’ TVDSS) and
approximately 230’ 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 CD4-587
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:
CD4-595: 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.
CD4-586: The 7 & 5/8” intermediate 2 liner was cemented on 08/02/2023. The primary cement
job was pumped as designed with 15.8 ppg Class G cement. The plug bumped and floats held
during the job, with no losses to formation. A SonicScope log was run with the 6 & ½” drilling
BHA on 06/18/2023 and the top of good cement is identified at 9,326 ftMD.
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.
CD4-588: The 7 & 5/8” intermediate 2 liner was cemented on 06/16/2023. The primary cement
job was pumped as designed with 15.8 ppg Class G cement. The plug bumped and floats held
during the job, with no losses to formation. A SonicScope log was run with the 6 & ½” drilling
BHA on 06/18/2023 and the top of good cement is identified at 11,450 ftMD.
Wells that do not transect the confining zone:
CD4-298: This well does not transect the K3 and Narwhal confining zone within ½ mile radius
of the proposed wellbore trajectory. CD4-298 is targeting Nanuq which is deeper than the
confining zone of K3 for Narwhal.
Narwhal is isolated. Top cement at 10,721' MD. Top Narwhal 13,767' MD (-4,036' TVDSS). SFD
PTD 223-046
12,355' MD SFDNarwhal is isolated. Top Narwhal 15,961' MD (-4,071' TVDSS). SFD
Narwhal is isolated. Top cement at 14,677' MD. Top Narwhal 16,368' MD (-4,088' TVDSS). SFD
Narwhal is isolated. Top Narwhal 14,972' MD (-4,044' TVDSS). SFD
*
PTD 219-115
*For CD4-539, Schlumberger's "Top of Cement Evaluation" presentation (dated Oct. 2, 2023) interprets free pipe from
7,943' to 8,600' MD, a transition zone of "weak/partial cement bond" from 8,600' to 9700' MD, and good cement bond
from 9,700' to 12,033' MD (-3,645' to -3,986' TVDSS). Top of Narwhal in that well is 12,524' MD (-4,005' TVDSS). SFD
Narwhal is isolated. See footnote below. SFD
PTD 223-029
Narwhal is isolated. Top Narwhal 13,314' MD (-4,002' TVDSS). SFD
PTD 223-063
Narwhal is isolated. Top Narwhal 12,945' MD (-4,002' TVDSS). SFD
PTD 218-123
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 CD4-587. The fault intersected the CD4-587 well
path at 6027’ 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
CD4-587, the fault was also encountered in the CD4-594 at 6297’ MD, CD4-595 at 6630’ MD,
CD4-597 at 6745’ MD, CD4-586 at 6155’ MD, CD4-588 at 6527’ MD, CD4-539 at 6460’ MD,
and CD4-536 at 6448’ MD. No losses were seen in any of the other wells in this fault. No other
faults were observed in the log data for the CD4-587.
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 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 CD4-539 wellbore.
Well Name
Fault
Depth MD
(ft)
Fault Depth
TVDSS (ft)
Fault Vertical
Displacement
(ft)
Fluid
Losses
(bbls/hr)
CD4-587 6027 -2949 60-90 0
CD4-536 6448 -3196 60-90 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
The fault intersected the CD4-587 well
path at 6027’ MD a
,
No losses were seen
ppg
encountered far above the reservoir interval in the overlying Seabee Formation
p
p, ,,
one fault or fracture system transected the confining zone g
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
CD4-587 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 17 ea dart actuated
sliding sleeves lower completion. The 1st stage will be pumped with initially dropping dart to
shift sleeve opened, sequentially continue to remaining dart actuated sleeves until stage 17.
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 1,463’ 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 17 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).
10,000 p
g
f 4,500
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
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Rig 26
To:Andrew Honea; DOA AOGCC Prudhoe Bay; Doyon 26 Driling Supervisor; Hobbs, Greg S; Regg, James B (OGC);
Brooks, Phoebe L (OGC)
Cc:Samuel Dye
Subject:Doyon 26 BOP Form
Date:Tuesday, December 12, 2023 4:05:25 PM
Attachments:12-11-2023 BOP Doyon 26.xlsx
Attached is a BOP form from Doyon 26, test date 12-11-23, 1 failure, manual choke, replaced manual
choke and retested good
Johnny Newman
Rig 26 Toolpusher
Rig26@doyondrilling.com
Rig Cell 907-301-1502
Office 907-670-4187
&ROYLOOH5LYHU8QLW&'
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:26 DATE: 12/11/23
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2230980 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/3850 Annular:250/2500 Valves:250/3850 MASP:1673
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water Inside BOP 2P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 18-3/4"x5000psi P Pit Level Indicators PP
#1 Rams 1 3-1/2"x6-5/8"P Flow Indicator PP
#2 Rams 1 Blind/Shear P Meth Gas Detector PP
#3 Rams 1 3-1/2"x6-5/8"P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8"x5000psi P Time/Pressure Test Result
HCR Valves 2 3-1/16" & 3-1/8"P System Pressure (psi)3100 P
Kill Line Valves 2 3" & 3-1/16"P Pressure After Closure (psi)1650 P
Check Valve 0NA200 psi Attained (sec)11 P
BOP Misc 0NAFull Pressure Attained (sec)127 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 3850 P
No. Valves 16 P ACC Misc 0NA
Manual Chokes 1FP
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 15 P
#1 Rams 15 P
Coiled Tubing Only:#2 Rams 13 P
Inside Reel valves 0NA #3 Rams 16 P
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures:1 Test Time:6.0 HCR Choke 1 P
Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 12/9/23 05:14
Waived By
Test Start Date/Time:12/11/2023 17:00
(date) (time)Witness
Test Finish Date/Time:12/11/2023 23:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Doyon
Test Annular W/ 4-1/2" Test Joint to 250/2500psi Low/High F/ 5min ea. Test #1 Rams & #3 Rams W/ 4-1/2" & 5-7/8" Test Joints,
Choke Manifold Valves #1-16, 4-1/2" & 5-7/8" FOSV's & Dart Valves all tested to 250/3850psi Low/High F/ 5min ea. Tested
Remote Choke Valve on Manifold to 1500psi. Test on Choke Manifold Manual Choke Valve failed, Replaced and Tested to
1500psi, good test. Tested flanges on Manual Choke Valve to 250/5000psi Low/High F/ 5min each.
J. Newman / A. Agnes
Conoco Phillips
R. Bjorhus / K. Harding
CRU CD4-587
Test Pressure (psi):
rig26@doyondrilling.com
d26cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2023-1211_BOP_Doyon26_CRU_CD4-587
9 9
9
9
9999
9
9
9
9
-5HJJ
FP
Choke Manifold Manual Choke Valve failed
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________COLVILLE RIV UNIT CD4-587
JBR 01/18/2024
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
Tested with 5 7/8" TJ. H2S Audible at drillers cab initially failed, calibrated, and passed. Test #9 Leaking test pump valve.
Repair and continue testing with no other failures.
Test Results
TEST DATA
Rig Rep:Einer FleagleOperator:ConocoPhillips Alaska, Inc.Operator Rep:Andy Lundale
Rig Owner/Rig No.:Doyon 26 PTD#:2230980 DATE:11/26/2023
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopSTS231201110448
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 7.5
MASP:
1673
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 P
#1 Rams 1 3 1/5 x 6 5/8 v P
#2 Rams 1 blind shear P
#3 Rams 1 3 1/2x 6 5/8 va P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/16 &3 1/8 P
Kill Line Valves 2 3& 3 1/16 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3075
Pressure After Closure P1645
200 PSI Attained P11
Full Pressure Attained P85
Blind Switch Covers:Pall stations
Bottle precharge P
Nitgn Btls# &psi (avg)P10@4000
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P FPH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P15
#1 Rams P14
#2 Rams P15
#3 Rams P14
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9
9
9999
9
9
9
H2S Audible at drillers cab initially failed,
FP
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, Coville River/Qannik Oil Pool, CRU CD4-587
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-098
Surface Location: 2461' FSL, 4780' FEL, Sec 19, T11N, R5E
Bottomhole Location: 4085' FSL, 566' FEL, Sec. 33, T11N R5E
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced 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 an AOGCCorder, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
*UHJRU\:LOVRQ
Commissioner
DATED this ___ day of October 2023.
Gregory Wilson Digitally signed by Gregory
Wilson
Date: 2023.10.31 14:44:33 -08'00'
31
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: 20669 TVD: 4190
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8.DNR Approval Number:13. Approximate Spud Date:
11/15/2023
Total Depth:9. Acres in Property:14. Distance to Nearest Property:
566' to ADL392675
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 73.1 15. Distance to Nearest Well Open
Surface: x-378427 y- 5957586 Zone- 4 19.1 to Same Pool: 21' to CD4-586
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 0 120 120
16" 13.375"68.0 L-80 Hyd563 80 0 0 135 135
12.25" 9.625"47.0 T-95 Hyd563 2942 0 0 2942 2428
8.75" 7"29.0 L-80 Hyd523 9209 0 0 9209 3518
6.125" 4.5"12.6 L-80 Hyd563 4557 9059 3448 13616 4068
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: Matt Nagel
Chris Brillon Contact Email:matt.b.nagel@conocophillips.com
Engineering Manager Contact Phone:
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
Colville River Unit,
Collville River/Qannik Oil Pool
907-263-4747
CRU CD4-587
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.
Total Depth MD (ft):
2724’ FSL, 4055’ FEL, Sec 28, T11N, R5E
4085’ FSL, 566’ FEL, Sec 33, T11N, R5E
LONS 97-007
P.O. Box 100360 Anchorage, Alaska, 99510-0360
ConocoPhillips Alaska, Inc
2818’ FSL, 4780’ FEL, Sec 19, T11N, R5E ADL384211, ADL380081, ADL391587
2485, 640, 640
59-52-180
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
18. Casing Program:Top - Setting Depth - BottomSpecifications
2092
Cement Volume MDSize
Plugs (measured):
(including stage data)
10 yds
1332sx 11 ppg & 330sx 15.8 ppg
Total Depth TVD (ft):
802sx 15.8 ppg Class G
1673
Conductor/Structural
LengthCasing
Authorized Title:
Authorized Signature:
Production
Liner
Intermediate
Authorized Name:
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):
678sx 15.8 ppg Class G
Uncemented liner w/ perf joints
Effect. Depth MD (ft):Effect. Depth TVD (ft):
Stratigraphic Test
No Mud log req'd: Yes No
No Directional svy req'd: Yes No
Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements
BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis
Single Well
Gas Hydrates
No Inclination-only svy req'd: Yes No
Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal
No
No
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 12:42 pm, Oct 17, 2023
13000
135
Diverter variance granted per 20 AAC 25.035(h)(2) -A.Dewhurst
-A.Dewhurst 23OCT23
223-098
3997
13616
3469
135
9059 4067
-A.Dewhurst 20OCT23
20669
9209
3448
2461
A.Dewhurst 23OCT23
X
DSR-10/19/23
2942
-A.Dewhurst 20OCT23
2428
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.
50-103-20867-00-00
VTL 10/31/2023
4190
$%8
Gregory Wilson Digitally signed by Gregory Wilson
Date: 2023.10.31 14:45:11 -08'00'
10/31/23
10/31/23
Type text hereType text hereRBDMS JSB 110223
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'
RBDMS JSB 1111Type text here
ϰͲϱϴϳ
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.
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
October 16th, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill CD4-587
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 November 15th, 2023. The intended rig used to drill the well is Doyon Rig 26.CD4-587 will be a fractured stimulated
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, CD4-586, and CD4-539 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 CD4-587. At CD4, there has not
been a significant indication of shallow gas hydrates through the surface hole interval.
It is requested that a variance to the blowout prevention equipment test frequency under 10 AAC 25.035(e)(10)(A) be granted for a 21-day
BOPE test schedule per the pilot project that Doyon 26 is currently on.
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:
Matt Nagel, (907) 263-4747 & matt.b.nagel@conocophillips.com,
or
Chris Brillon, (907) 265-6120 & Chris.l.Brillon@conocophillips.com
Sincerely, cc:
CD4-587 Well File / Jenna Taylor ATO 1560
David Lee ATO 1726
Chris Brillon ATO 1548
Matt Nagel Andy Mack Kuukpik
Drilling Engineer
AOGCC Application for Permit to Drill, Well CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-23
CD4-587
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 CD4-587
Attachment 6: Wellhead Schematic
AOGCC Application for Permit to Drill, Well CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-23
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as CRU CD4-587.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface (CD4-587 Slot) 2818’ FSL, 4780’ FEL, Sec 19, T11N, R5E
NAD 27
Northings: 5957586
Eastings: 378427
RKB Elevation 73.1’ AMSL
Pad Elevation 19.1’ AMSL
Location at Productive Horizon (Heel) 2724’ FSL, 4055’ FEL, Sec 28, T11N, R5E
NAD 27
Northings: 5954395
Eastings: 389674
Measured Depth, RKB: 13,787’
Total Vertical Depth, RKB: 4085’
Total Vertical Depth, SS: 4,011’
Location at Total Depth (Toe) 4085’ FSL, 566’ FEL, Sec 33, T11N, R5E
NAD 27
Northings: 5948426
Eastings: 393091
Measured Depth, RKB: 20,669’
Total Vertical Depth, RKB: 4,190’
Total Vertical Depth, SS: 4,117’
Requirements of 20 AAC 25.050(b)
Please see Attachment 5: CD4-587 wp10.1 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 CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-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 2,942 / 2,428 14.4 1,052 1,184
9-5/8 9,209 / 3,518 14.2 1,575 1,411
7-5/8 13,616 / 4,067 14.6 1,818 1,673
4-1/2 20,669 / 4,190 15.0 2,092 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 2,428) = 809 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 2,428’ = 1,575 psi
OR
ASP = FPP – (0.1 x D)
= 1,536 – (0.1 x 3,518’) = 1,184 psi
AOGCC Application for Permit to Drill, Well CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-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 3,518 = 2,246 psi
OR
ASP = FPP – (0.1 x D)
= 1,818 – (0.1 x 4,067) = 1,411 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 4,067 = 2,680 psi
OR
ASP = FPP – (0.1 x D)
= 2,092 – (0.1 x 4,190) = 1,673 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
80 0 0 135 135 10 yds
16" 13.375" 68.0 L-80 H563 2942 0 0 2942 2428 1332sx 11 ppg & 330sx 15.8
ppg
12.25" 9.625" 47.0 T-95 H563 9209 0 0 9209 3518 802sx 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 4557 9059 3448 13616 4068 678sx 15.8 ppg Class G (TOC
1500’MD above K3 sand)
6.5" 4.5" 12.6 P-110S H563 7669 13000 3997 20669 4190 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 6 previously drilled wells (CD4-289, CD4-298, CD4-302, CD4-290, CD4-594, and CD4-586) within 500’
and 3 previously drilled wells (CD4-302, CD4-499, CD4-209) within 1000’ of the proposed CD4-587 surface shoe
location. None of these wells encountered any significant indication of shallow gas or gas hydrates.
AOGCC Application for Permit to Drill, Well CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-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.
1111111111RBDMS JSB 110223
AOGCC Application for Permit to Drill, Well CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-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 CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-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 +/-2,942’ MD / 2,428’ 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 +/-9,209’ MD / 3,518’ 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 +/-7,776’ MD / 3,268’ 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 +/-13,616’ MD / 4,067’ 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 +/-10,363’ MD / 3,631’ 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 CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-23
formations. Offset wells CD4-595, CD4-594, CD4-597, CD4-588, CD4-586, CD4- 539 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 +/- 20,669’ MD / 4,190’ TVD using MPD
as per directional plan. Run MWD/LWD logging tools (LMWD Program: GR/RES/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
111Type text here11
AOGCC Application for Permit to Drill, Well CD4-587
Saved: 16-Oct-23
CD4-587 AOGCC APD
Printed: 16-Oct-23
Attachment 1 – Cement Summary
13-3/8” Surface Casing
9-5/8” Intermediate 1 Casing
7-5/8” Intermediate 2 Casing
1.16 ft^3/sk 1.92 ft^3/sk
25.1 bbls
299.7 bbls
130.8 bbls
455.6 bbls or 2558 ft^3 or 1332 sks
12.0 bbls
56.2 bbls
68.2 bbls or 382.7 ft^3 or 330 sks
428.5 bblsDisplacement = (2942' - 80') x 0.1497 bbl/ft =
Total Tail Cement =
Tail Cement yield =
CONDUCTOR =
Shoe to Top of Tail = (2942' - 2442') x 0.0749 bbl/ft x 1.5 (50% excess)
Total Lead Cement =
135' x 0.1862 bbl/ft x 1.0 (0% excess)
Base of Permafrost to COND = (1278' - 135') x 0.0749 bbl/ft x 3.5 (250% excess)
11.0 ppg DeepCRETE Lead Slurry
15.8 ppg Class G Tail Slurry
Shoetrack = 80' x 0.1497 bbl/ft x 1.0 (0% excess)
13-3/8" SURFACE CEMENT CALCULATIONS
Lead Cement yield =
Design: 500' of 15.8ppg Tail Cmt with 11.0ppg Lead Cmt to surface with 50% excess below Permafrost & 250%
excess in Permafrost
Btm of Lead to Base of Permafrost = (2442' - 1278') x 0.0749 bbl/ft x 1.5 (50% excess)
1.16 ft^3/sk
8.8 bbls
156.9 bbls
165.6 bbls or 930 ft^3 or 802 sks
665.4 bbls
Total Cement Volume =
Displacement = 9089' x 0.0732 bbl/ft =
9-5/8" Intermediate I Cement Calculations
Design: Class G 15.8 ppg Cement to 250' TVD above shoe set depth.
Cement yield = Planned TOC = 7046' MD
Shoe Track 120' x 0.0732 bbl/ft x 1.0 (0% excess)
12-1/4" x 9-5/8" Annulus = (9209' - 7046') x 0.0558 bbl/ft x 1.3 (30% excess)
1.16 ft^3/sk 1.96 ft^3/sk
8.3 bbls
131.9 bbls
140.2 bbls or 787 ft^3 or 678 sks
430.5 bbls
7.625" Intermediate II Cement Calculations
Design: 15.8 ppg class G tail to 1500' MD above K3 marker.
Tail Cement yield = Lead Cement yield =
15.8 ppg Class G Tail Slurry
Shoetrack = 180' x 0.0459 bbl/ft x 1.0 (0% excess)
Shoe to Top of Tail = 3253' x 0.0312 bbl/ft x 1.3 (30% excess)
(13436' - 8550') x 0.0459 bbl/ft + 8550' x 0.0243 bbl/ft =
Total Tail Cement =
Displacement =
11111111RBDMS JSB 110223
Attachment 2 CD4-587 Drilling Hazards
Summary
16" Hole / 13-3/8” Casing Interval
Hazard Risk Level Mitigation Strategy
Conductor Broach Low Monitor cellar continuously during interval.
Gas Hydrates Low Monitor well at base of permafrost, controlled drilling
rates, low mud temperatures. Additions of Lecithin.
Lost Circulation Low
Monitor real time equivalent circulating density (ECD) to
below expected formation fracture gradient. Prepare
enough lost circulation material on location. Reduce
drilling ROP and trip speed when necessary.
Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of
hole if necessary.
Anti-Collision Low
Monitor real time surveys closely, run gyro survey to
eliminate magnetic interference from nearby wells when
needed.
Washouts / Hole Sloughing Moderate Keep mud temperatures as low as possible, minimize
circulating time when possible.
12-1/4” Hole / 9-5/8” Casing Interval
Hazard Risk Level Mitigation Strategy
Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and
torque/drag real time.
Abnormal Reservoir Pressure Low
Monitor pit volumes while drilling and tripping, flow
check on connections. Shallow hazard analysis performed
and suggests low risk of abnormal pressure.
Lost Circulation Low
Monitor ECD to below expected formation fracture
gradient. Prepare enough lost circulation material on
location. Reduce drilling ROP and trip speed when
necessary.
Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of
hole if necessary.
8-1/2” x 9-1/2” Hole / 7-5/8” Liner Interval
Hazard Risk Level Mitigation Strategy
Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and
torque/drag real time.
Abnormal Reservoir Pressure Low
Monitor pit volumes while drilling and tripping, flow
check on connections. Shallow hazard analysis performed
and suggests low risk of abnormal pressure. Narwhal
Central Sand PP expected to be ~8.9 ppg.
Lost Circulation Moderate
Monitor real time equivalent circulating density (ECD) to
below expected formation fracture gradient. Prepare
enough lost circulation material on location. Reduce
drilling ROP and trip speed when necessary.
6-1/2" Open Hole / 4-1/2” Liner Interval
Hazard Risk Level Mitigation Strategy
Abnormal Reservoir Pressure Low
Monitor pit volumes while drilling and tripping, flow
check on connections. Narwhal Central Sand PP expected
to be ~9.0 ppg.
Stuck Pipe Low Keep good hole cleaning practices, use PWD tools
monitoring and analysis, stabilized BHA.
Lost Circulation Moderate Reduced pump rates, mud rheology, use LCM program,
control ECD below expected fracture gradient.
Differential Sticking Low Follow mud program, keep pipe moving when able.
Getting Liner to bottom Moderate Monitor T&D real time for early signs of issues, properly
clean hole prior to pulling out of hole to run liner.
Hole swabbing on trips Moderate Use proper tripping speed, monitor proper hole fill (use
of trip sheets), pumping backreaming out if necessary.
CD4-587
Narwhal Central Sand Producer
(Doyon 26 RKB = 73.1')
Surface Casing:
13-3/8" 68# L80 H563
2,942’ MD / 2,428' TVD – 55° Inc
Conductor Installed:
20" set @ 135' MD / TVD
Production Liner:
4-1/2" 12.6# TN110S/P110S H563
Intermediate 1:
9-5/8" 47# T95 H563 @ 9,209' MD / 3,469' TVD – 82° Inc
Tubing: 4-½” 12.6# L80 H563
12-1/4" Intermediate 1 Hole
6-1/2" Production Hole
16" Surface Hole
Narwhal Central Sand Top:
13,788' MD / 4,085' TVD
Intermediate 2:
7-5/8" 29.7# L80 H523
7-5/8" 39# P110S H523 (500' heavy heel) w/ 29.7# Shoetrack
@ 13,616' MD / 4,067' TVD – 84° Inc
7-5/8" x 9-5/8" Liner hanger: 9,652' MD / 3,518' TVD
TOC @ 7,776‘ MD / 3,268' TVD
FMC Big Bore Well Head
WP 10.1 Last Update: 9/29/23 MW
Silverwell
DHG and GL
DIAL mandrel
TOC @10,363' MD / 3,631' TVD
K-3 Top: Possible Sand Stringers
11,863' MD / 3,840' TVD
4-½” Citadel MOAS Shoe
3.75" DB
3.813" X CMD
Sliding Sleeve
3.813" HAL X nipple
8-1/2” x 9-1/2” Under-Reamed
Intermediate 2 Hole
Production TD:
@ ± 20,669' MD / 4,190' TVD
4-1/2” x 7-5/8" Baker SLZXP Liner Hanger Packer 13,000' MD
DrilPlex WBM
10.5ppg
FWP WBM
10.8 ppg
FWP WBM
9.0 ppg
VersaPro OBM
8.0ppg
Diesel
6.8ppg
~1300' TVD
GLMGLM
GLM
Brine
10.0 ppg
Production Packer
Silver
well
11RBDMS JSB 110223
PIKKA UNIT
COLVILLE RIVER UNIT
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-
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C
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-
7
7
C
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1
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8
C
D
2
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3
C
D
4
-
2
1
1
C
D
2
-
2
7
C
D
1
-
4
8
A
CD4-302
C
D
4
-
2
9
1
P
B
1
C
D
4
-
2
9
2
C
D
4
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9
1
N
A
N
U
Q
5
C
D
4
-
2
9
0
C
D
4
-
3
2
0
C
D
4
-
4
9
9
C
D
4
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8
9
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D
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B
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1
A
C
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C
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1
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9
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P
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D
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3
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8
A
C
D
4
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1
B
C
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7
C
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4
ADL388902
ADL372097
ADL392981
ADL380077
ADL391587
ADL393167
ADL372095
ADL392975
ADL393166
ADL384209
ADL372096
ADL392961
ADL380075
ADL380081
ADL380044
ADL388903
ADL384211
ADL380082
ADL384210
ADL391590
ADL025559
ADL393168
ADL380079
CD4
k
10/2/2023
S:\ANC\Longterm\AK GIS\WNS\DM\CRU_Wells\CD4\CD4_587\CD4-587_PRO_Project\
CD4-587
PTD Map
010.5
Miles
Open Interval
Well Trajectory
Dev Well: P&A
Dev Well: Active
Narwhal PA
Unit Boundary
2 Pad
CPAI
Industry Lease
C
D
4
-
5
8
7
54 500
500 1000
1000 1500
1500 2000
2000 3000
3000 5000
5000 8000
8000 12000
12000 16000
16000 20568
CD4-587 wp10.1 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
7" Intermediate Casing
4-1/2" Production Liner
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]
54
118218318
417
516615713810
CD4-289
54
117
217
317416
515
CD4-290
1902
1996
2092
CD4-298
1902
1996
2092
54
100200300400500601701801
901
1001
1101
1200
1299
CD4-586
54100200300400500599698797
895
994
1091
1189
CD4-588
2250
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 121.06°
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7" Intermediate Casing
4-1/2" Production Liner
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
Equivalent Magnetic Distance
DDI
7.209
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
54.00 1400.00 CD4-587 wp10.1 (CD4-587) SDI_URSA1_I4
1400.00 2400.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
1400.00 2990.00 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
2990.00 3990.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
2990.00 9700.00 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
9700.00 10700.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
9700.00 13610.00 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
13610.00 14610.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
13610.00 20668.87 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
Surface Location
North / 5957333.22
East / 1518460.78
Ground / 19.10
CASING DETAILS
TVD MD Name2448.31 2997.97 13-3/8" Surface Casing
3538.82 9705.24 9-5/8" Intermediate Casing
4067.34 13615.61 7" Intermediate Casing4190.10 20668.87 4-1/2" Production Liner
Mag Model & Date: BGGM2023 20-Jan-24
Magnetic North is 14.05° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.54° 57169.76nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 54.00 0.00 0.00 54.00 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 2.00 101.00 499.96 -0.67 3.43 1.00 101.00 3.28 Start Build 1.50
4 700.00 5.00 101.00 699.56 -3.00 15.41 1.50 0.00 14.75 Start Build 2.50
5 1225.33 18.13 101.00 1213.10 -23.05 118.58 2.50 0.00 113.47 Start 105.23 hold at 1225.33 MD
6 1330.56 18.13 101.00 1313.10 -29.30 150.73 0.00 0.00 144.24 Start Build 3.25
7 2872.71 68.25 101.00 2401.90 -224.35 1154.16 3.25 0.00 1104.44 Start 20.00 hold at 2872.71 MD
8 2892.71 68.25 101.00 2409.31 -227.89 1172.39 0.00 0.00 1121.89 Start 500.00 hold at 2892.71 MD
9 3392.71 68.25 101.00 2594.56 -316.50 1628.28 0.00 0.00 1558.13 Start DLS 2.75 TFO -1.98
10 3890.24 81.93 100.53 2722.27 -406.02 2099.49 2.75 -1.98 2007.97 Start 7899.17 hold at 3890.24 MD
1111789.41 81.93 100.53 3831.48 -1834.81 9788.77 0.00 0.00 9332.02 Start DLS 2.75 TFO 90.84
1213539.49 84.00 149.00 4059.38 -2796.24 11171.01 2.75 90.8411012.13 Start 600.00 hold at 13539.49 MD
1314139.49 84.00 149.00 4122.10 -3307.72 11478.34 0.00 0.0011539.28 CD4-NE3A (C) T1 092723 Start 20.00 hold at 14139.49 MD
1414159.49 84.00 149.00 4124.19 -3324.77 11488.59 0.00 0.0011556.85 Start DLS 2.00 TFO 2.68
1514447.24 89.75 149.27 4139.87 -3571.29 11635.93 2.00 2.6811810.26 Start 2540.01 hold at 14447.24 MD
1616987.25 89.75 149.27 4151.01 -5754.60 12933.89 0.00 0.0014048.55 Start DLS 1.00 TFO 171.87
1717002.27 89.60 149.29 4151.10 -5767.51 12941.56 1.00 171.8714061.79 CD4-NE3A (C) T2 092723 Start DLS 1.00 TFO 170.89
1817023.54 89.39 149.32 4151.29 -5785.80 12952.42 1.00 170.8914080.53 Start 3645.33 hold at 17023.54 MD
19 20668.87 89.39 149.32 4190.10 -8920.84 14812.12 0.00 0.0017291.05 CD4-NE3A (C) T3 092723 TD at 20668.87
FORMATION TOP DETAILS
TVDPath Formation
1263.10 Base Perm
2204.98 C-40
2448.31 C-30
2766.16 C-20
3037.20 Fault 1
3046.51 C-10
3841.89 K-3
4085.34 Top Narwhal (Central)
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 18.4+54 @ 73.10usft (D26)
-2
5
0
0
0
25
0
0
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0
0
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True Vertical Depth
0
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0
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0
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0
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1
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15000
16000
17000
18000
19000
20000
20669
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82°
84°
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0
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0
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0 450 900 1350 1800 2250
Partial Measured Depth
CD4-289
CD4-290
CD4-298
CD4-298PB1
CD4-588
CD4-586
Equivalent Magnetic Distance
CD4-587 wp10.1 Ladder View
0
150
300
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
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t
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0 3000 6000 9000 12000 15000 18000 21000
Measured Depth
Nanuk
1
CD4-03
CD4-289
CD4-290
CD4-291
CD4-291PB1
CD4-292
CD4-298
CD4-298PB1
CD4-301
CD4-301A
CD4-301B
CD4-302
CD4-499
CD4-588
CD4-586
CD4-594
CD4-594PH1
CD4-595
CD4-595PH1
CD4-597
CD4-93
CD4-93A
CD4-96
CD4-96A
CD4-96APB1
CD4-541
wp07 (NE4A C)
Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
54.00 1400.00 CD4-587 wp10.1 (CD4-587) SDI_URSA1_I4
1400.00 2400.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
1400.00 2990.00 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
2990.00 3990.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
2990.00 9700.00 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
9700.0010700.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
9700.0013610.00 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
13610.0014610.00 CD4-587 wp10.1 (CD4-587) MWD OWSG
13610.00 20668.87 CD4-587 wp10.1 (CD4-587) MWD+IFR2+SAG+MS
10:21, September 28 2023
CASING DETAILS
TVD MD Name
2448.31 2997.97 13-3/8" Surface Casing
3538.82 9705.24 9-5/8" Intermediate Casing
4067.34 13615.61 7" Intermediate Casing
4190.10 20668.87 4-1/2" Production Liner
54 500
500 1000
1000 1500
1500 2000
2000 3000
3000 5000
5000 8000
8000 12000
12000 16000
16000 20669
CD4-587 wp10.1 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]
54
68118168
218268
318
367417467
5165666156647137628108599079551003
1050
1097
1144
1191
1238
1287
1335
1380
1425
CD4-289
54
67117
167217267
317367416466
515564613662711759808855903
950
998
1045
1093
1140
1187
123412841333CD4-290
5468118168218268318
3674164665155646136617107578058529009469931039108611321178CD4-291
5468118168218268318
3674164665155646136617107578058529009469931039108611321178CD4-291PB1
54
67117167217267317366416
465514563611660708755803850896942987
CD4-292
13501396
1441
14861531157716231669171517621808185519021949
1996
2044
2092
2140
2188
2237
2286
2335
2385
2436
2486
2536
2587
2637
2687CD4-298
13501396
1441
14861531157716231669171517621808185519021949
1996
2044
2092
2140
2188
2237
2286
2335
2385
2436
2486
2536
2587
2637
2687CD4-298PB1
169717431789183518811927197420202066211321602207225423002347239324402486253225772622CD4-302
541001502002503003504004505005495996496987487978468959459941043
1091
1140
1189
1237
1287
1336
1384
1431
1479
1527
1574
1622
1669
1716CD4-588
54
100150
200250300
35040045050055160165170175180185190195110011051110111501200
12501299
1349
1398
1448
1497
1547
1596
1645
1694
1743
1792
1841
1890
142601430814356144041445214501145511460114650147001475014800148491489914949149991504915099151491519915248152981534815398154481549815548155981564815698157481579815848158981594815998
16048160981614716197162471629716347163971644716497165471659716647166971674716797
168461689616946169961704717097CD4-586
5477127177227277326375424473522570619667715763811858906954
1001105010971145119312411292134113881436148315311579162716751723177118201868191719662015206421132162221122602310235924082457250625562605265427032752280128502899294929983048
3098
3147
3196
3245
3294
CD4-594
5477127177227277326375424473522570619667715763811858906954
100110501097114511931241
1292134113881436148315311579162716751723177118201868191719662015206421132162221122602310235924082457250625562605265427032752280128502899294929983048
3098
3147
3196
3245
3294
CD4-594PH1
5474124174224274324373421470519567615663711759806853900948
995
1042
CD4-595
5474124174224274324373421470519567615663711759806853900948
995
1042
CD4-595PH1
5468118168218268317366415464513562610
658
706
752
800
845
890
CD4-93
5467117167217267317366415464513561609657
705
752
798
844
890
CD4-93A
3243
3290
3337
3384
3428
3472
3516
3561
3606
3652
3698
CD4-541 wp07 (NE4A C)
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
From To Tool
54.00 1400.00 SDI_URSA1_I4
1400.00 2400.00 MWD OWSG
1400.00 2990.00 MWD+IFR2+SAG+MS
2990.00 3990.00 MWD OWSG
2990.00 9700.00 MWD+IFR2+SAG+MS
9700.00 10700.00 MWD OWSG
9700.00 13610.00 MWD+IFR2+SAG+MS
13610.00 14610.00 MWD OWSG
13610.00 20668.87 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name2448.31 2997.97 13-3/8" Surface Casing3538.82 9705.24 9-5/8" Intermediate Casing4067.34 13615.61 7" Intermediate Casing4190.10 20668.87 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 54.00 0.00 0.00 54.00 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 2.00 101.00 499.96 -0.67 3.43 1.00 101.00 3.28 Start Build 1.50
4 700.00 5.00 101.00 699.56 -3.00 15.41 1.50 0.00 14.75 Start Build 2.50
5 1225.33 18.13 101.00 1213.10 -23.05 118.58 2.50 0.00 113.47 Start 105.23 hold at 1225.33 MD
6 1330.56 18.13 101.00 1313.10 -29.30 150.73 0.00 0.00 144.24 Start Build 3.25
7 2872.71 68.25 101.00 2401.90 -224.35 1154.16 3.25 0.00 1104.44 Start 20.00 hold at 2872.71 MD
8 2892.71 68.25 101.00 2409.31 -227.89 1172.39 0.00 0.00 1121.89 Start 500.00 hold at 2892.71 MD
9 3392.71 68.25 101.00 2594.56 -316.50 1628.28 0.00 0.00 1558.13 Start DLS 2.75 TFO -1.98
10 3890.24 81.93 100.53 2722.27 -406.02 2099.49 2.75 -1.98 2007.97 Start 7899.17 hold at 3890.24 MD
1111789.41 81.93 100.53 3831.48 -1834.81 9788.77 0.00 0.00 9332.02 Start DLS 2.75 TFO 90.84
1213539.49 84.00 149.00 4059.38 -2796.24 11171.01 2.75 90.8411012.13 Start 600.00 hold at 13539.49 MD
1314139.49 84.00 149.00 4122.10 -3307.72 11478.34 0.00 0.0011539.28 CD4-NE3A (C) T1 092723 Start 20.00 hold at 14139.49 MD
1414159.49 84.00 149.00 4124.19 -3324.77 11488.59 0.00 0.0011556.85 Start DLS 2.00 TFO 2.68
1514447.24 89.75 149.27 4139.87 -3571.29 11635.93 2.00 2.6811810.26 Start 2540.01 hold at 14447.24 MD
1616987.25 89.75 149.27 4151.01 -5754.60 12933.89 0.00 0.0014048.55 Start DLS 1.00 TFO 171.87
1717002.27 89.60 149.29 4151.10 -5767.51 12941.56 1.00 171.8714061.79 CD4-NE3A (C) T2 092723 Start DLS 1.00 TFO 170.89
1817023.54 89.39 149.32 4151.29 -5785.80 12952.42 1.00 170.8914080.53 Start 3645.33 hold at 17023.54 MD
19 20668.87 89.39 149.32 4190.10 -8920.84 14812.12 0.00 0.0017291.05 CD4-NE3A (C) T3 092723 TD at 20668.87
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3 53739414345Nanuk 2
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CD4-210
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CD4-210A
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CD4-210B
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CD4-211
3 5
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CD4-211L1 3 5
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CD4-213
3 53739414345CD4-213A
3 53739414345
CD4-213B
3 53739414345
CD4-213BPB1
3 53739414345
CD4-213BPB2
3 53 73 94 14345
CD4-214
3 53 73 94 14345
CD4-214L1
3 5373941434 5
CD4-215
3 5373941434 5
CD4-215L1
3 53 73 94 14 34 5
CD4-23
3 53 73 94 14 34 5
CD4-23PB1
3 53 73 94 14 34 5
CD4-23PB2
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CD4-24
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CD4-24PB1
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CD4-24PB2
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CD4-25
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CD4-27
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CD4-27PB1
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CD4-27PB2
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CD4-27PB3
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CD4-289
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CD4-290
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CD4-291
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3
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3
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35
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CD4-298
35
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35
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43
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CD4-301
35
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41
43
45
CD4-301A
35
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43
45
CD4-301B
353739414345
CD4-302
353739
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45
CD4-304
353739
4143
45
CD4-304PB1
35
37
39
41
43
45
CD4-306
3 53 73 94 14 34 5
CD4-318
3 53 73 94 14 34 5
CD4-318A
3 53 73 94 14 34 5
CD4-318PB1
353739414345
CD4-319
353739414345
CD4-320
353739414345
CD4-320PB1
3 5
3 7
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4 1
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CD4-321
35
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CD4-322
353
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CD4-49935
37
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CD4-536 wp06
35
37
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CD4-539
35
37
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CD4-539 wp10.2
35
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CD4-588
35
37
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CD4-586
35
37
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35
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CD4-594PH1
35
3
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CD4-595
35
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3
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CD4-597
35
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CD4-93
35
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3 53 73 94 14 34 5
CD4-96
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3 53739414345
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3
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o
t
10
:
3
1
,
S
e
p
t
e
m
b
e
r
2
8
2
0
2
3
54
.
0
0
T
o
2
0
6
6
8
.
8
7
Northing (1500 usft/in)
Ea
s
t
i
n
g
(
1
5
0
0
u
s
f
t
/
i
n
)
35
3 739414345Nanuk 1
35 37 3
9 4
1 43 45
CD4-03
CD4-05
CD4-07
3 5
3 7
3 9
4 1
4 3CD4-12
3 5
3 7
3 9
4 1
4 3CD4-12PB1
3
5 3
7 3
9 4
1 4
3 4
5
Nanuq 5
CD4-16
CD4-17
3
5
3
73
94
1
43
45
CD4-208
35
37
39
41
43
45
CD4-208A
35
37
39
41
43
45
CD4-208AL1
35
37
39
41
43
45
CD4-208APB1
3
5
3
73
94
1
43
45
CD4-208PB1 353739414345
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
35
37
39
41
43
45
CD4-289
353739414345
CD4-290
353739414345
CD4-291
353739414345
CD4-291PB1
3
5
3
7
3
9
4
1
4
3
4
5
CD4-292
35
37 39
4 1
43
45
CD4-298
35
37 39
4 1
43
45
CD4-298PB1
35
37
39
41
43
45
CD4-301
35
37
39
41
43
45
CD4-301A
35
37
39
41
43
45
CD4-301B
35
37
39
41
43
45
CD4-302
CD4-304
CD4-304PB1
CD4-306
CD4-318
CD4-318A
CD4-318PB1
CD4-319
353739414345
CD4-320
353739414345
CD4-320PB1
CD4-321
CD4-322
35
3
7
3
9
4
1
CD4-499
35
37
39
4
1
CD4-536 wp06
35
37
39
4
1
CD4-539
35
37
39
4
1
CD4-539 w
p10.2
35
37
3
9
4
1
CD4-588
35
37
39
41
4
3
CD4-586
35
37
39
4
1
CD4-594
35
37
39
41
43
45
CD4-594PH1
35
CD4-595
35
CD4-595PH1
3
5
3
7
3
9 CD4-597
CD4-93
CD4-93A
CD4-96
CD4-96A
CD4-96APB1
Nanuq 3
3
5 3
7
CD4-529 wp01
3
5
3
7
3
9
CD4-530 wp01
3
5
3
7
CD4-531 wp02
3
5
3
7
CD4-532 wp01
3
5
3
7
3
9
4
1
CD4-533 wp01
3
5
3
7
3
9
CD4-534 wp01
35
37
39
4
1
CD4-535 wp01
3 5
3 7
39
CD4-537 wp02 (NE5B C)
35
37
3
9
4
1
CD4-541 wp07 (NE4A C)
3 5
CD4-542 wp01
35
37
39
4
1
CD4-587 wp10.1
CD
4
-
5
8
7
w
p
1
0
.
1
Sp
i
d
e
r
P
l
o
t
10
:
3
3
,
S
e
p
t
e
m
b
e
r
2
8
2
0
2
3
54
.
0
0
T
o
2
0
6
6
8
.
8
7
Northing (800 usft/in)
Ea
s
t
i
n
g
(
8
0
0
u
s
f
t
/
i
n
)
2 022242628303234
36
3 8404244
Nanuk 1
20 22 2
4 26 28 30
32
CD4-03
2 0CD4-05
CD4-07
2
0 2
2
2
4 2
6 28
30
32
34
3 6
3 8
4 0
4 2CD4-12
2
0 2
2
2
4 2
6 28
30
32
34
3 6
3 8
4 0
4 2CD4-12PB1
2
0 2
2
2
4
2
6
2
8
3
0
3
2
3
4
3
6
Nanuq 5
CD4-16
CD4-17
2
0 22 2
4 2
6 2
8 3
0 3
2 3
4 3
6 3
8 4
0 4
2 44
CD4-208
2
0 22 2
4 26
28
30
32
34
36
38
40
42
44
CD4-208A
2
0 22 2
4 26
28
30
32
34
36
38
40
42
44
CD4-208AL1
2
0 22 2
4 26
28
30
32
34
36
38
40
42
44
CD4-208APB1
2
0 22 2
4 2
6 2
8 3
0 3
2 3
4 3
6 3
8 4
0 4
2 44
CD4-208PB1
20222426283032343638404244
CD4-209
20
22CD4-210 20
22
CD4-210A
20
22
CD4-210APB1
20
22CD4-210B
2 0
CD4-211
2 0
CD4-211L1
2 0CD4-211L1-01
20
CD4-213
20
CD4-213A
20
CD4-213B
20
CD4-213BPB1
20
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
20
22
24
26
28
30
32
34
36
38
40
42
44
D4-289
20
22
24
26
28
30
32
34
36
38
40
42
44
CD4-290
20222426283032343638404244
CD4-291
20222426283032343638404244
CD4-291PB1
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
CD4-292
20
22
24
26
28
30
32
34
36
38
4 0
4 2
44
CD4-298
20
22
24
26
28
30
32
34
36
38
4 0
4 2
44
CD4-298PB1
20
22
24
26
28
30
32
34
36
38
40
42
44
20
22
24
26
28
30
32
34
36
38
40
42
44
CD4-301A
20
22
24
26
28
30
32
34
36
38
40
42
44
CD4-301B
20
22
24
26
28
30
32
34
36
38
40
42
44
CD4-302
20
22CD4-304 20
22CD4-304PB1
20
CD4-306
CD4-318
CD4-318A
CD4-318PB1
CD4-319
20222426283032343638404244
CD4-320
20222426283032343638404244
CD4-320PB1
CD4-321
CD4-322
20
2224
26
28
30
32
34
36
3
8
4
0
CD4-499
20
22
24
26
28
30
32
34
CD4-536 wp06
20
22
24
26
28
30
32
34
36
CD4-539
20
22
24
26
28
30
32
34
36
CD4-539 w
2 0
2 2
2 4
2 6
2 8
3 0
3 2
CD4-588
2 0
2 2
2 4
26
28
30
32
34
CD4-586
20
22
24
26
28
30
32
CD4-594
20
22
24
26
28
30
32
D4-594PH1
2
0
2
2
2
4
2
6
28
CD4-595
2
0
2
2
2
4
2
6
28 CD4-595PH1
2
0
2
2
2
4
2
6
2
8
30
CD4-597
20
22
CD4-93
20
22
CD4-93A
20
22
CD4-96
20
22
CD4-96A
20
22
CD4-96APB1
Nanuq 3
CD4-529 wp01
2
0 2
2
2
4
2
6
2
8
3
0
CD4-530 wp01
2
0
2
2
2
4
2
6
2
8
3
0
CD4-531 wp02
2
0
2
2
2
4
2
6
2
8
3
0
CD4-532 wp01
2
0
2
2
2
4
2
6
2
8
3
0
3
2 CD4-533 wp01
2
0
2
2
2
4
2
6
2
8
3
0
CD4-534 wp01
20
22
24
26
28
3
0
32
34 CD4-535 wp01
2 0
2 2
2 4
2 6
28
3 0
3 2
3 4
CD4-537 wp02 (NE5B C)
20
22
24
26
2 8
3 0
CD4-541 wp07 (NE4A C)
2 0
2 2
2 4
2 6
2 8
3 0
3 2
CD4-542 wp01
20
22
24
26
28
30
32
CD4-587 wp10.1
CD
4
-
5
8
7
w
p
1
0
.
1
Sp
i
d
e
r
P
l
o
t
10
:
3
6
,
S
e
p
t
e
m
b
e
r
2
8
2
0
2
3
54
.
0
0
T
o
2
0
6
6
8
.
8
7
Northing (200 usft/in)
Ea
s
t
i
n
g
(
2
0
0
u
s
f
t
/
i
n
)
2 022242628303234
36
3 8404244
Nanuk 1
20
22
24
26
28
30
32
34
36
CD4-289
20
22
24
26
28
30
32
34
36
38
40
42
44
CD4-290
20
22
24
26
28
30
32
34
36
38
40
42
44
CD4-291
20
22
24
26
28
30
32
34
36
38
40
42
44
CD4-291PB1
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
CD4-292
20
2 2
24
26 CD4-298
20
2 2
24
26
CD4-298PB1
20
22
24
CD4-301
20
22
24
CD4-301A
20
22
24
CD4-301B
20
22
24
26
28
30
32
CD4-302
CD4-320
CD4-320PB1
2 0
22
24
26
28
30
32
34
36
3
8
CD4-499
22
24
CD4-536 wp06
20
22
CD4-539
20
22
CD4-539 wp10.2
2 0
2 2
2 4
2 6
CD4-588
2 0
2 2
2 4
26
28
CD4-586
20
22
24
26
CD4-594
20
22
24
26
CD4-594PH1
2
0
CD4-595
2
0
CD4-595PH1
2
0
2
2
CD4-597
CD4-93
CD4-93A 22
CD4-535 wp01
2 2
2 4
2 6
28
3 0
CD4-537 wp02 (NE5B C)
20
22
24
26
CD4-541 wp07 (NE4A C)
2 0
2 2
2 4
2 6
CD4-542 wp01
20
22
24
26
CD4-587 wp10.1
CD
4
-
5
8
7
w
p
1
0
.
1
Sp
i
d
e
r
P
l
o
t
10
:
4
2
,
S
e
p
t
e
m
b
e
r
2
8
2
0
2
3
54
.
0
0
T
o
2
0
6
6
8
.
8
7
Northing (25 usft/in)
Ea
s
t
i
n
g
(
2
5
u
s
f
t
/
i
n
)
1
2
3 45678
9
1 0
1 1
1 2
1 3
1 4
1 5
16
1 7
CD4-289
1 23
4
5 6 7
8
9
1
0
CD4-290
1234510
1 1
12
13
14
15
16
17
18
19
CD4-291
1234510
1 1
12
13
14
15
16
17
18
19
CD4-291PB1
1 3
1 4
1 5
16
CD4-298
1 3
1 4
1 5
16
CD4-298PB1
12 3456
7
8
9
1 0
1 1
12
1 3
1 4
CD4-588
123456
7
8
9
1 0
1 1
1 2
CD4-586
10
11
12
13
14
CD4-594
10
11
12
13
14
D4-594PH1
1 9
2 0
2 1
CD4-542 wp01
1234
5
6
7
8
9
10
11
12
13
CD4-587 wp10.1
CD
4
-
5
8
7
w
p
1
0
.
1
CD
4
-
2
8
9
CD
4
-
2
9
0
CD
4
-
2
9
1
CD
4
-
2
9
1
P
B
1
CD
4
-
2
9
2
CD
4
-
2
9
8
CD
4
-
2
9
8
P
B
1
CD
4
-
3
0
1
CD
4
-
3
0
1
A
CD
4
-
3
0
2
CD
4
-
3
2
0
CD
4
-
4
9
9
CD
4
-
5
8
8
CD
4
-
5
8
6
CD
4
-
5
9
4
P
H
1
CD
4
-
5
3
7
w
p
0
2
(
N
E
5
B
C
)
CD
4
-
5
4
1
w
p
0
7
(
N
E
4
A
C
)
3-
D
V
i
e
w
CD
4
-
5
8
7
w
p
1
0
.
1
10
:
4
7
,
S
e
p
t
e
m
b
e
r
2
8
2
0
2
3
CD
4
-
5
8
7
w
p
1
0
.
1
CD
4
-
2
9
8
CD
4
-
2
9
8
P
B
1
CD
4
-
3
0
1
CD
4
-
3
0
1
A
CD
4
-
5
8
8
CD
4
-
5
8
6
CD
4
-
5
9
4
P
H
1
CD
4
-
5
3
7
w
p
0
2
(
N
E
5
B
C
)
CD
4
-
5
4
1
w
p
0
7
(
N
E
4
A
C
)
CD
4
-
5
4
2
w
p
0
1
3-
D
V
i
e
w
CD
4
-
5
8
7
w
p
1
0
.
1
10
:
4
7
,
S
e
p
t
e
m
b
e
r
2
8
2
0
2
3
-1
0
0
0
0
-8
0
0
0
-6
0
0
0
-4
0
0
0
-2
0
0
0
0
South(-)/North(+) (2000 usft/in)
60
0
0
8
0
0
0
1
0
0
0
0
1
2
0
0
0
1
4
0
0
0
1
6
0
0
0
1
8
0
0
0
2
0
0
0
0
2
2
0
0
0
We
s
t
(
-
)
/
E
a
s
t
(
+
)
(
2
0
0
0
u
s
f
t
/
i
n
)
C
D
4
-
2
8
9
C
D
4
-
2
9
0
C
D
4
-
2
9
8
C
D
4
-
2
9
8
P
B
1
409041104130415041704190
C
D
4
-
3
0
1
409041104130415041704190
C
D
4
-
3
0
1
A
409041104130415041704190
C
D
4
-
3
0
1
B
CD4-302
C
D
4
-
4
9
9
4
0
5
0
4
0
7
0
4
0
9
0 4
1
1
0
4
1
3
0
4150
4
1
7
0 4
1
9
0
C
D
4
-
5
3
6
w
p
0
6
4050407
0 4
0
9
0
4
1
1
0
4
1
3
0
4
1
5
0 4
1
7
0
4
1
9
0
C
D
4
-
5
3
9
4
0
5
0
4
0
7
0
4
0
9
0
4
1
1
0
4
1
3
0
4
1
5
0
4
1
7
0
4
1
9
0
C
D
4
-
5
8
8
40504070409041104130415041704190
C
D
4
-
5
8
6
405
0
4
07
0
40
9
0
4
1
1
0
4
1
3
0
4
1
5
0
4
1
7
0
4
1
9
0
C
D
4
-
5
9
4
4050
4070
4090
4110
4130
4150
4170
4190
C
D4-594P
H1
4
0
5
0
4
0
7
0
4
0
9
0
4
1
1
0
4
1
3
0
4
1
5
0
4
1
7
0
4
1
9
0
C
D
4
-
5
9
5
4
0
5
0
4
0
7
0
4
0
9
0
4
1
1
0
4
1
3
0
4
1
5
0
4
1
7
0
4
1
9
0
C
D
4-5
9
5
P
H
1
4
0
5
0
4
0
7
0
4
0
9
0
4
1
1
0
4
1
3
0
4
1
5
0
4
1
7
0
4
1
9
0
C
D
4
-
5
9
7
4
0
5
0
4
0
7
0
4
0
9
0
4
1
1
0
4
1
3
0
4
1
5
0
4
1
7
0
4
1
9
0
C
D
4
-
5
3
1
w
p
0
2
4
1
5
0
C
D
4
-
5
3
2
w
p
0
1
4
1
1
0
4
1
3
0
4
1
5
0
C
D
4
-
5
3
3
w
p
0
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CD4-587wp10.1 Surface Location
CD4-587wp10.1 Surface Location
CD4-537wp10.1 Surface Casing
CD4-537wp10.1 Surface Casing
CD4-537wp10.1 Intermediate Casing 1
CD4-537wp10.1 Intermediate Casing 1
CD4-537wp10.1 Intermediate Casing 2
CD4-537wp10.1 Intermediate Casing 2
CD4-537wp10.1 Top Narwhal Central
CD4-537wp10.1 Top Narwhal Central
CD4-537wp10.1 TD
CD4-537wp10.1 TD
PHONE : 907-670-4739
PHONE : 907-670-4739
F
S TH49
T
OEAT
A
LAA
K
S
UMIAQ Design & Municipal
Services, LLC / AECL1316
1
Dewhurst, Andrew D (OGC)
From:Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent:Friday, October 20, 2023 18:21
To:Dewhurst, Andrew D (OGC)
Cc:Hobbs, Greg S; Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC)
Subject:RE: [EXTERNAL]RE: CRU CD4-587 (PTD 223-098): Question
Attachments:CD4-587 wp10.1 surf loc.pdf
Andy,
CorrectSHLis2461’FSL.I’veaƩachedthescreenshotfortheSHL.
Thanks
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Sent:Friday,October20,20233:43PM
To:Nagel,MattB<Matt.B.Nagel@conocophillips.com>
Cc:Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,
MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>
Subject:[EXTERNAL]RE:CRUCD4Ͳ587(PTD223Ͳ098):Question
MaƩ,
OnelastquesƟon.I’mtryingtosortoutaSHLdiscrepancy.WouldyoupleaseconĮrmtheSHL(Governmental
SecƟons/LegalDescripƟon)?IwasexpecƟng~2460’FSL.
Thesescreenshotsareveryhelpful,butIdon’tseeonefortheSHL:
2
Thanks,
Andy
From:Nagel,MattB<Matt.B.Nagel@conocophillips.com>
Sent:Friday,October20,202312:27
To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Cc:Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,
MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>
Subject:RE:[EXTERNAL]CRUCD4Ͳ587(PTD223Ͳ098):Question
Andy,
Yes,thosecasingdepthcorrecƟonsareaccurate.
I’veaƩachedafullyupdated10Ͳ401.
Thankyou
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
3
From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Sent:Friday,October20,202311:50AM
To:Nagel,MattB<Matt.B.Nagel@conocophillips.com>
Cc:Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,
MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>
Subject:[EXTERNAL]CRUCD4Ͳ587(PTD223Ͳ098):Question
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.
MaƩ,
IamcompleƟngthereviewoftheCRUCD4Ͳ587andIhaveaquesƟonforyou:
x WouldyoupleaseconĮrmthefollowingcorrecƟonsforthecasingprogramdepthsonthe10Ͳ401form:
Thanks,
Andy
AndrewDewhurst
SeniorPetroleumGeologist
AlaskaOilandGasConservaƟonCommission
333W.7thAve,Anchorage,AK99501
andrew.dewhurst@alaska.gov
Direct:(907)793Ͳ1254
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 no greater
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.
CRU CD4-587
X
QANNIK OIL POOL
223-098
COLVILLE RIVER
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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
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
12
0
'
c
o
n
d
u
c
t
o
r
d
r
i
v
e
n
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
SC
s
e
t
a
t
2
9
4
2
'
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
13
6
%
e
x
c
e
s
s
c
e
m
e
n
t
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
p
e
r
f
j
o
i
n
t
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
e
t
e
r
w
a
i
v
e
r
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
f
o
r
m
a
t
i
o
n
p
r
e
s
s
u
r
e
i
s
2
0
9
2
p
s
i
g
(
9
.
9
p
p
g
E
M
W
)
;
w
i
l
l
d
r
i
l
l
w
/
8
-
1
1
p
p
g
E
M
W
u
t
i
l
i
z
i
n
g
M
P
D
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
6
7
3
p
s
i
g
;
w
i
l
l
t
e
s
t
B
O
P
s
t
o
5
0
0
0
p
s
i
g
i
n
i
t
i
a
l
l
y
a
n
d
3
5
0
0
p
s
i
g
s
u
b
s
e
q
u
e
n
t
l
y
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
Wo
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
No
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
Na
r
w
h
a
l
"
C
e
n
t
r
a
l
"
s
a
n
d
a
n
t
i
c
i
p
a
t
e
d
t
o
b
e
~
9
.
0
p
p
g
E
M
W
.
M
P
D
t
o
b
e
e
m
p
l
o
y
e
d
i
n
p
r
o
d
u
c
t
i
o
n
h
o
l
e
.
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
10
/
2
0
/
2
0
2
3
Ap
p
r
VT
L
Da
t
e
10
/
3
0
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
10
/
2
0
/
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
*&
:
