Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-10-05_23054_CRU_CD4-586_CoilFlag_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
23054 CRU CD4-586 50-103-20857-00 Coil flag 05-Oct-24
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
10/8/2024
223-046
T39637
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.10.08 11:46:17
-08'00'
Originated: Delivered to:5-Jul-24
Alaska Oil & Gas Conservation Commiss 05Jul24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24
CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24
2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24
1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24
CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24
CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24
3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24
2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24
2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24
2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24
MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24
MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T39122
T39123
T39124
T39125
T39126
T39127
T39128
T39129
T39130
T39131
T39132
T39133
CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.05 10:30:21 -08'00'
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-17_22604_CRU_CD4-586_ProductionProfile_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
22604 CRU CD4-586 50-103-20857-00 Production Profile 17-May-24
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ ______________________________________
Date received Signature
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
223-046
T38849
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.28 11:11:47
-08'00'
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-17_22604_CRU_CD4-586_CoilFlag_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
22604 CRU CD4-586 50-103-20857-00 Coil Flag 17-May-24
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ ______________________________________
Date received Signature
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
223-046
T38848
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.28 11:10:30 -08'00'
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:CD4-586
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: CD4-586 e-transmittal well folder
Receipt: Date:
Alaska/IT Data Services-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
CD4-586
PTD: 223-046
T38484
2/5/2024Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2024.02.05
10:55:12 -09'00'
TTT RR AA NN SS MM II TT TT AA LL
FROM:: Sandra D. Lemke, ATO-704 TO:: Kayla Junke ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 7th Avenue, Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska
RE: CD4-586
DATE: 11/09/2023
Transmitted:
North Slope, Colville River Unit, Alaska
Via SFTP upload
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: CD4-586 e-transmittal well folder
Receipt: Date:
Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 223-046
T38124
11/8/2023Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.11.08
10:11:58 -09'00'
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ŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚƚŽŵĂƚĐŚƚŚĞŵĞĚŝĂŶŽƚĞĚĂďŽǀĞ͘dŚĞƐƉĞĐŝĨŝĐ
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η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ
PTD: 223-046
T38018
Kayla Junke 9/29/2023
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.09.29
09:41:02 -08'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 4920' FSL, 418' FWL S28 T11N R5E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 18.9 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" X65 133'50.5bbl
13-3/8 L-80 2397'
9-5/8" T-95 3432'
7-5/8" L-80 4057'
4 1/2" P11OS 4353'
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
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Tail: 136bbl 15.8ppg Class G
8.5"x9 7/8"
TUBING RECORD
19753'
Lead: 168.1 bbl 15.8ppg Class G
4003'
12-1/4"
6.5'
12463'4.5 12351'MD/3989' TVD
12468'MD/3967' TVD
BOTTOM
16" Lead: 377bbl 11ppg Class G
Tail: 72bbl 15.8ppg Class G
CASING
50-103-20857-00-00
CRU CD4-586
7/10/2023
20736'MD/4365'TVD
N/A
73.44
P.O.Box 100360, Anchorage, AK 99510-0360
378445
2465' FSL, 4762' FEL S19 T11N R5E
3849' FSL,4725' FWL S33 T11N R5E
8/13/2023
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
8/24/2023 223-046/323-396
1274'MD/1260'TVD
SETTING DEPTH TVD
5948191
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER, mud log
PACKER SET (MD/TVD)
12457'
42"
12.6
5957589
Colville River Field/ Narwhal Undefined Oil
Pool
ADL384221, ADL380082, ADL380081,
ADL391587
LONS 97-007
54'
29.7
54'
7639'
2721'
WT. PER
FT.GRADE
388869
393099
CEMENTING RECORD
5954603
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
54'
54'
Per 20 AAC 25.283 (i)(2) attach electronic information
47
12822'
52'
3412'
154
68
133'
52' 7801'
SIZE DEPTH SET (MD)
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Liner (8/19/23): 12457'MD/4003'TVD - 19753'MD/4353'TVD88
RECEIVED BY JAMES BROOKS ON 9/20/2023
Completed
8/24/2023
JSB
RBDMS JSB 101023
GDSR-10/13/23
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1274 1260
C-40 2429 2212
2804 2444
3433 2763
C-10 4448 3032
K3 11232 3849
12945 4076
20736 4365
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: Joe Longo
Digital Signature with Date:
Contact Phone:907-265-6824
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:
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
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:joseph.j.longo@conocophillips.com
Authorized Title: Drilling Engineer
C-20
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.
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:CD4-586 8/26/2023 oberr
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Post Rig, BPV Pulled, Pre Frac SOV, MIT-T, MIT-IA CD4-586 8/26/2023 oberr
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 18.50 54.0 133.0 133.0 154.19 X65
Surface 13 3/8 12.42 54.3 2,721.0 2,396.7 68.00 L80 HYD563
Intermediate 1 9 5/8 8.68 52.0 7,800.9 3,432.2 47.00 T95 H563
Intermediate 2 7 5/8 6.88 7,639.2 12,822.0 4,056.9 29.70 L-80 TSH 523
Liner 4 1/2 3.96 12,456.7 19,752.6 4,352.5 12.60 P110S H563
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
49.2
Set Depth …
12,463.0
Set Depth …
4,004.2
String Ma…
4 1/2
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)
49.2 49.2 0.00 Hanger 11.000 FMC 4-1/2" Tubing Hanger Hydril
HYD 563 Min ID 3.92"
FMC TC-EMS 3.958
1,292.2 1,276.8 20.96 Nipple - X 4.500 NIPPLE,LANDING,4 1/2","X",3.813",
H563
HES X Nipple 3.813
3,201.3 2,659.3 60.77 Mandrel – GAS
LIFT
4.500 4-1/2" x 1" KBG4-5 GLM 12.6# H563 Camco KBG4-5 3.865
12,118.9 3,959.9 82.82 Sleeve - Sliding 4.500 Sliding Sleeve, CMD, 4.5" x 3.813"
GX profile, Vam Top, Down to open
Baker Nexo-2 3.813
12,178.9 3,967.4 82.82 Mandrel – GAS
LIFT
4.500 4-1/2" x 1" KBG4-5 GLM 12.6# H563 Camco KBG4-5 3.865
12,246.3 3,975.8 82.88 Gauge / Pump
Sensor
4.500 Schlumberger Downhole Gauge
Mandrel 4-1/2 w/ Metris Evolve
Single Gauge, 12.6# H563
SLB Metris
Evolve
single
3.920
12,350.9 3,989.0 82.47 Packer 6.880 HAL TNT Packer,PN 713TNT7517-Z
7-5/8", 26.4#-39#, 4 1/2, 12.6# VAM
TOP
HES TNT 3.856
12,417.2 3,997.9 82.12 Nipple - DB 4.500 NIPPLE,LANDING,4
1/2","DB",3.750", H563
SLB DB-6
nipple
3.750
12,438.8 4,000.8 82.02 Sub - Shear
Out - SOS
5.750 Arsenal glass plug, 5500 psi, 4-1/2,
4140, H563 **Sheared 9/3/23**
3.910
12,454.1 4,003.0 81.94 Locator 5.290 Mechanical locator shear sub (No
Go -.62 from top)
Baker 3.900
12,460.4 4,003.9 81.91 Shoe - Mule 4.500 HES Self orienting mule shoe HES 4.120
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)
3,201.3 2,659.3 60.77 1 GAS LIFT DMY BK 1 0.0 8/26/2023 KBG4-5 0.000
12,178.9 3,967.4 82.82 2 GAS LIFT DMY BK 1 0.0 8/22/2023 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)
12,467.8 4,004.9 81.88 Packer 6.400 Baker SLZXP (HRD-E) Packer SLZXP
LTP
H29647004
8
4.800
12,479.0 4,006.5 81.88 XO Reducing 5.530 Crossover 5-1/2" H563 pin x 4-
1/2" 12.6# H563 pin, 110 MYS
material
3.910
13,392.6 4,148.1 80.12 Packer - Swell 4.500 Baker Oil Swell Packer #17, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
13,579.0 4,178.0 82.05 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#6, 4-1/2" 12.6# C110 HYD563
Advance
d
Upstrea
m
3.505
13,745.1 4,196.9 84.70 Packer - Swell 4.500 Baker Oil Swell Packer #16, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
13,931.4 4,210.6 87.05 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#5, 4-1/2" 12.6# C110 HYD563
Advance
d
Upstrea
m
3.505
14,056.6 4,215.4 88.54 Packer - Swell 4.500 Baker Oil Swell Packer #15, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
14,241.5 4,217.3 89.96 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#4, 4-1/2" 12.6# C110 HYD563
Advance
d
Upstrea
m
3.505
14,405.8 4,218.2 89.22 Packer - Swell 4.500 Baker Oil Swell Packer #14, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
14,592.3 4,221.2 88.75 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#3, 4-1/2" 12.6# C110 HYD 563
Advance
d
Upstrea
m
3.505
14,801.6 4,227.7 87.54 Packer - Swell 4.500 Baker Oil Swell Packer #13, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
14,987.4 4,237.1 86.81 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#2, 4-1/2" 12.6# C110 HYD563
Advance
d
Upstrea
m
3.505
HORIZONTAL, CD4-586, 9/20/2023 10:18:01 AM
Vertical schematic (actual)
Liner; 12,456.7-19,752.6
Hydraulic fracture; 19,575.8
Hydraulic fracture; 19,178.3
Hydraulic fracture; 18,822.8
Hydraulic fracture; 18,425.4
Hydraulic fracture; 18,027.9
Hydraulic fracture; 17,675.1
Hydraulic fracture; 17,277.6
Hydraulic fracture; 16,880.2
Hydraulic fracture; 16,524.0
Hydraulic fracture; 16,126.7
Hydraulic fracture; 15,728.6
Hydraulic fracture; 15,378.0
Hydraulic fracture; 14,984.8
Hydraulic fracture; 14,589.7
Hydraulic fracture; 14,238.9
Hydraulic fracture; 13,928.8
Hydraulic fracture; 13,576.4
Intermediate 2; 7,639.2-12,822.0
Sub - Shear Out - SOS;
12,438.8
Packer; 12,350.9
Mandrel – GAS LIFT; 12,178.8
Sleeve - Sliding; 12,118.9
Liner Cement; 9,732.0 ftKB
Intermediate 1; 52.0-7,800.9
Intermediate String 1 Cement;
5,747.0 ftKB
Mandrel – GAS LIFT; 3,201.3
Surface; 54.3-2,721.0
Primary – Full Bore; 54.4 ftKB
Conductor; 54.0-133.0
Conductor String Cement; 57.0
ftKB
Hanger; 49.2
WNS PROD
KB-Grd (ft)
54.04
RR Date
8/24/2023
Other Elev…
CD4-586
...
TD
Act Btm (ftKB)
20,736.0
Well Attributes
Field Name
NARWHAL
Wellbore API/UWI
501032085700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
92.47
MD (ftKB)
19,501.35
WELLNAME WELLBORECD4-586
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)
15,194.1 4,247.2 87.79 Packer - Swell 4.500 Baker Oil Swell Packer #12, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
15,380.6 4,253.3 88.38 Sleeve - Frac 5.000 Advanced Upstream frac sleeve
#1, 4-1/2" 12.6# C110 HYD563
Advance
d
Upstrea
m
3.505
15,548.3 4,257.7 88.49 Packer - Swell 4.500 Baker Oil Swell Packer #11, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
15,731.3 4,262.8 88.38 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#11, 4-1/2" 12.6# C110 HYD563,
ball OD 3.464"
Frac
sleeve
H80934000
4
3.429
15,942.4 4,268.8 88.43 Packer - Swell 4.500 Baker Oil Swell Packer #10, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
16,129.3 4,273.7 88.50 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#10, 4-1/2" 12.6# C110 HYD563,
ball OD 3.419"
Frac
sleeve
H80934000
5
3.383
16,340.4 4,279.6 88.48 Packer - Swell 4.500 Baker Oil Swell Packer #9, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
16,526.6 4,284.7 88.45 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#9, 4-1/2" 12.6# C110 HYD563,
ball OD 3.373"
Frac
sleeve
H80934000
6
3.339
16,696.4 4,290.4 87.23 Packer - Swell 4.500 Baker Oil Swell Packer #8, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
16,882.8 4,300.8 86.23 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#8, 4-1/2" 12.6# C110 HYD563,
ball OD 3.329"
Frac
sleeve
H80934000
7
3.294
17,093.9 4,316.0 85.89 Packer - Swell 4.500 Baker Oil Swell Packer #7, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
17,280.2 4,328.0 87.23 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#7, 4-1/2" 12.6# C110 HYD563,
ball OD 3.284"
Frac
sleeve
H80934000
8
3.251
17,491.2 4,333.8 89.08 Packer - Swell 4.500 Baker Oil Swell Packer #6, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
17,677.7 4,339.1 87.86 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#6, 4-1/2" 12.6# C110 HYD563,
ball OD 3.241"
Frac
sleeve
H80934000
9
3.207
17,844.1 4,346.7 87.27 Packer - Swell 4.500 Baker Oil Swell Packer #5, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
18,030.6 4,355.4 87.33 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#5, 4-1/2" 12.6# C110 HYD563,
ball OD 3.197"
Frac
sleeve
H80934001
0
3.164
18,241.3 4,363.7 88.46 Packer - Swell 4.500 Baker Oil Swell Packer #4, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
18,428.1 4,367.6 88.91 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#4, 4-1/2" 12.6# C110 HYD563,
ball OD 3.154"
Frac
sleeve
H80934001
1
3.122
18,639.0 4,370.6 89.73 Packer - Swell 4.500 Baker Oil Swell Packer #3, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
18,825.4 4,371.2 89.91 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#3, 4-1/2" 12.6# C110 HYD563,
ball OD 3.112"
Frac
sleeve
H80934001
2
3.080
18,995.1 4,371.1 90.27 Packer - Swell 4.500 Baker Oil Swell Packer #2, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
19,180.9 4,369.8 90.40 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#2, 4-1/2" 12.6# C110 HYD563,
ball OD 3.07"
Frac
sleeve
H80934001
3
3.038
19,391.8 4,366.8 91.59 Packer - Swell 4.500 Baker Oil Swell Packer #1, 4-1/2"
12.6# P110S HYD563 (with
Hydroform 4.5 x 5.75)
Baker 3.950
19,578.4 4,359.6 92.33 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve
#1, 4-1/2" 12.6# C110 HYD563,
ball OD 3.028"
Frac
sleeve
H80934001
4
2.997
HORIZONTAL, CD4-586, 9/20/2023 10:18:02 AM
Vertical schematic (actual)
Liner; 12,456.7-19,752.6
Hydraulic fracture; 19,575.8
Hydraulic fracture; 19,178.3
Hydraulic fracture; 18,822.8
Hydraulic fracture; 18,425.4
Hydraulic fracture; 18,027.9
Hydraulic fracture; 17,675.1
Hydraulic fracture; 17,277.6
Hydraulic fracture; 16,880.2
Hydraulic fracture; 16,524.0
Hydraulic fracture; 16,126.7
Hydraulic fracture; 15,728.6
Hydraulic fracture; 15,378.0
Hydraulic fracture; 14,984.8
Hydraulic fracture; 14,589.7
Hydraulic fracture; 14,238.9
Hydraulic fracture; 13,928.8
Hydraulic fracture; 13,576.4
Intermediate 2; 7,639.2-12,822.0
Sub - Shear Out - SOS;
12,438.8
Packer; 12,350.9
Mandrel – GAS LIFT; 12,178.8
Sleeve - Sliding; 12,118.9
Liner Cement; 9,732.0 ftKB
Intermediate 1; 52.0-7,800.9
Intermediate String 1 Cement;
5,747.0 ftKB
Mandrel – GAS LIFT; 3,201.3
Surface; 54.3-2,721.0
Primary – Full Bore; 54.4 ftKB
Conductor; 54.0-133.0
Conductor String Cement; 57.0
ftKB
Hanger; 49.2
WNS PROD CD4-586
...
WELLNAME WELLBORECD4-586
Page 1/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/7/2023
06:00
7/7/2023
09:30
3.50 MIRU, MOVE RURD P Unhook interconnects between sub
base / pits; sub base / pipe shed; pump
module / pits. Prep modules to move.
0.0 0.0
7/7/2023
09:30
7/7/2023
12:00
2.50 MIRU, MOVE MOB P Stomp pipe shed away from sub base.
Move motor module away and stage.
Move CPU away from pits and stage on
pad.
0.0 0.0
7/7/2023
12:00
7/7/2023
13:00
1.00 MIRU, MOVE MOB P Hook onto pump module with truck.
Move pump module away from pits &
stage on pad.
0.0 0.0
7/7/2023
13:00
7/7/2023
15:30
2.50 MIRU, MOVE MOB P Skid rig floor into move position. 0.0 0.0
7/7/2023
15:30
7/7/2023
18:00
2.50 MIRU, MOVE MOB P Move sub base forward. Set sub down &
turn tires to move sub out of way to
stage.
0.0 0.0
7/7/2023
18:00
7/7/2023
19:00
1.00 MIRU, MOVE MOB P Continue to position drill module tires.
Move sub base out of the way of BOP
module to stage on pad. SIMOPS
remove 3" brace bracket on drill module
for pin kits to clear; connect tow arm to
BOP module.
0.0 0.0
7/7/2023
19:00
7/7/2023
20:45
1.75 MIRU, MOVE MOB P Secure BOP module out riggers. Skid
BOP module to well house. Hook up
truck & pull BOP module off of CD4-588.
0.0 0.0
7/7/2023
20:45
7/7/2023
22:00
1.25 MIRU, MOVE MOB P Mobilize and secure 18-3/4" low
pressure in lower cellar of BOP module.
Clear & clean around cellar box. Prep
pad to lay rig mats for BOP module.
0.0 0.0
7/7/2023
22:00
7/8/2023
00:00
2.00 MIRU, MOVE MOB P Spot BOP module over CD4-586. Shim
module. Secure out riggers in place &
verify level.
0.0 0.0
7/8/2023
00:00
7/8/2023
01:30
1.50 MIRU, MOVE MOB P Continue to level out riggers & adjust
level of pad beneath them. SIMOPS
extract bolt on pin kit for BOP module.
0.0 0.0
7/8/2023
01:30
7/8/2023
03:00
1.50 MIRU, MOVE MOB P Move sub base over to line up with BOP
module. Turn tires to travel back to BOP
module and well center.
0.0 0.0
7/8/2023
03:00
7/8/2023
07:00
4.00 MIRU, MOVE MOB P Move sub base into place & pin to BOP
module. Unpin, reposition sub & pin
back up to BOP module. Shim BOP
module. Apply 500 psi to out riggers &
lock in place.
0.0 0.0
7/8/2023
07:00
7/8/2023
08:00
1.00 MIRU, MOVE MOB P Skid rig floor into drill position. 0.0 0.0
7/8/2023
08:00
7/8/2023
09:00
1.00 MIRU, MOVE MOB P Back up pipe shed module with truck.
Install weather stripping boots around
opening.
0.0 0.0
7/8/2023
09:00
7/8/2023
11:00
2.00 MIRU, MOVE MOB P Stomp pipe shed module into place and
shim. Back spot pit module in place with
truck. Stomp pit module into place.
0.0 0.0
7/8/2023
11:00
7/8/2023
12:00
1.00 MIRU, MOVE MOB P Move pump room module into position
with truck. Stomp pump module into
place. Move CPU into place with truck.
Hook up interconnect lines between
BOP module / pits & BOP module / sub
base.
0.0 0.0
7/8/2023
12:00
7/8/2023
13:00
1.00 MIRU, MOVE MOB P Move motor module in place with truck.
Stomp same in place. SIMOPS continue
to hook up interconnects.
0.0 0.0
7/8/2023
13:00
7/8/2023
14:15
1.25 MIRU, MOVE MOB P Stomp CPU in place. SIMOPS continue
to hook up interconnects.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 2/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/8/2023
14:15
7/8/2023
18:00
3.75 MIRU, MOVE RURD P Work on rig acceptance checklist. Plug
in all modules & take cold start
generators off-line. Continue hooking up
interconnects. Install dump chute in
CPU. Install steam traps. Install
Geronimo line. Install surface adapter &
riser on conductor. Test to 1000 psi for 5
minutes per FMC.
RKB to landing ring 54.37'; to ground
level 54.54.
0.0 0.0
7/8/2023
18:00
7/8/2023
21:30
3.50 MIRU, MOVE RURD P Work on rig acceptance checklist.
Change air boots on flow line & bell
nipple. Turn on water throughout the
modules. SIMOPS install & torque up
FMC surface adapter. Stage surface
risers on rig floor & BOP deck.
Accept rig at 21:30 hrs.
0.0 0.0
7/8/2023
21:30
7/9/2023
00:00
2.50 MIRU, MOVE RURD P Stack up surface risers & adapter.
Complete CPU auger chute. Test pit
suction valves. SIMOPS Load 13-3/8"
casing into pipe shed.
0.0 0.0
7/9/2023
00:00
7/9/2023
02:00
2.00 MIRU, MOVE RURD P Pick up & make up to 90' mouse hole &
XY crane mouse hole. Load 93 joints of
5-7/8" drill pipe in the shed. Load mud
products in the pits. Change screens on
the shakers.
0.0 0.0
7/9/2023
02:00
7/9/2023
04:15
2.25 MIRU, MOVE SLPC P Hang the blocks & top drive. Cut and
slip 83' of drill line. Service & inspect top
drive, saver sub, & grabber dies.
Change out wash pipe. Inspect
drawworks brakes. Unhang blocks & top
drive. Secure block hanging line.
SIMOPS load 93 joints of 5-7/8" drill
pipe in the shed.
0.0 0.0
7/9/2023
04:15
7/9/2023
06:00
1.75 MIRU, MOVE SVRG P Change out saver sub on top drive.
Remove torque ring on saver sub.
Change out saver sub. Torque to 85K
per SOP. Install torque ring. Perform full
block height & hook load calibration.
SIMOPS service ST-120.
0.0 0.0
7/9/2023
06:00
7/9/2023
07:00
1.00 MIRU, MOVE RURD P Prep to install spare air boots on riser.
Chain off kill line valve 3. Install 2" high
pressure fittings on surface adapter.
Stock mud product in the pits. Start
derrick inspection.
0.0 0.0
7/9/2023
07:00
7/9/2023
10:15
3.25 MIRU, MOVE RURD P Mobilize casing equipment to the rig
floor & rig up same. Make up landing
joint & 13-3/8" casing hanger. Perform
dummy run to land out on depth of
54.37' RKB. Lay down hanger & landing
joint. Rig down casing equipment &
mobilize from rig floor to ground.
0.0 0.0
7/9/2023
10:15
7/9/2023
18:30
8.25 MIRU, MOVE PULD P Pick up and rack back 31 stand of 5-7/8"
drill pipe. Run in and tag bottom of the
conductor at 129' MD.
0.0 0.0
7/9/2023
18:30
7/9/2023
21:00
2.50 MIRU, MOVE BHAH P Mobilize BHA components to the rig
floor. SIMOPS clear rig floor, repair ST-
120, perform BWM on BOPE.
0.0 0.0
7/9/2023
21:00
7/9/2023
22:00
1.00 MIRU, MOVE PULD P Pick up 2 stands of HWDP & 1 JAR
stand, racking back in the derrick.
0.0 0.0
7/9/2023
22:00
7/10/2023
00:00
2.00 MIRU, MOVE BHAH P Pick up 16" surface BHA 1 from surface
to 86' MD as per SLB DD. Scribe Gyro /
TeleScope per DD & Gyro hand.
0.0 86.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 3/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/10/2023
00:00
7/10/2023
01:30
1.50 MIRU, MOVE BHAH P Continue picking up 16" surface section
BHA1 as per SLB DD from 86'-129' MD.
Make up a stand of HWDP from the
derrick to the BHA & top drive.
86.0 129.0
7/10/2023
01:30
7/10/2023
01:45
0.25 MIRU, MOVE SFTY P PJSM for flooding all line, filling the
conductor & pressure testing.
129.0 129.0
7/10/2023
01:45
7/10/2023
02:45
1.00 MIRU, MOVE SEQP P Flood high pressure mud lines,
conductor & flow line to pits with 10.5
ppg DrilPlex mud. Check all lines, good.
Pressure test high pressure mud lines to
5500 psi, good.
129.0 129.0
7/10/2023
02:45
7/10/2023
04:45
2.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 129'-
213' MD, 213' TVD.
600 gpm; 590 psi; 28% FO
40 rpm; Tq on 2K; off 1K
WOB 5K
PU 98K; SO 98K; ROT 97K
ADT 1.54; AST .0; Bit hrs 1.54; Jar hrs.
0
129.0 213.0
7/10/2023
04:45
7/10/2023
05:00
0.25 SURFAC, DRILL TRIP P TOH from 213'-125' MD, PU 90K. Rack
back 1 stand of HWDP.
213.0 125.0
7/10/2023
05:00
7/10/2023
05:45
0.75 SURFAC, DRILL BHAH P Pick up and make up remaining BHA
components per SLB DD.
125.0 125.0
7/10/2023
05:45
7/10/2023
06:00
0.25 SURFAC, DRILL TRIP P TIH from 125'-213' MD, SO 98K. 125.0 213.0
7/10/2023
06:00
7/10/2023
09:30
3.50 SURFAC, DRILL DDRL P Drill 16" surface hole section from 213'-
363' MD, 363' TVD.
600 gpm; 650 psi; 40% FO
40 rpm; Tq on 2K; off 1K
WOB 5K
PU 103K; SO 103K; ROT 103K
ADT 1.87; AST .47; Bit hrs. 3.41; Jar
hrs. 0
213.0 363.0
7/10/2023
09:30
7/10/2023
09:45
0.25 SURFAC, DRILL TRIP P TOH from 363'-271' MD, PU 103K. Rack
back 1 stand of HWDP.
363.0 271.0
7/10/2023
09:45
7/10/2023
10:00
0.25 SURFAC, DRILL TRIP P TIH with JAR stand from 271'-363' MD. 271.0 363.0
7/10/2023
10:00
7/10/2023
11:30
1.50 SURFAC, DRILL DDRL P Drill 16" surface hole section from 363'-
415' MD, 415' TVD.
600 gpm; 650 psi; 40% FO
40 rpm; Tq on 2K; off 1K
WOB 5K
PU 103K; SO 103K; ROT 103K
ADT .51; AST .24; Bit hrs 3.92; Jar hrs.
.51
363.0 415.0
7/10/2023
11:30
7/10/2023
12:00
0.50 SURFAC, DRILL OTHR T Pick up off bottom and circulate at 1
bpm, 72 psi. Clear lines & chute to CPU.
415.0 415.0
7/10/2023
12:00
7/10/2023
12:15
0.25 SURFAC, DRILL DDRL P Drill 16" surface hole section from 415'-
420' MD, 420' TVD.
650 gpm; 830 psi; 30% FO
0 rpm; Tq on 0K; off 0K
WOB 5-10K
PU 103K; SO 103K; ROT 103K
ADT .06; AST .06; Bit hrs 3.98; Jar hrs.
.57
415.0 420.0
7/10/2023
12:15
7/10/2023
13:30
1.25 SURFAC, DRILL OTHR T Pick up off bottom and circulate at 1-2
bpm, 70-80 psi. Clear dump lines in
CPU and transfer lines to MagTec.
420.0 420.0
7/10/2023
13:30
7/10/2023
14:30
1.00 SURFAC, DRILL TRIP T TOH from 420'-119' MD, PU 96K.
SIMOPS Clear dump lines in CPU and
transfer lines to MagTec.
420.0 119.0
7/10/2023
14:30
7/10/2023
16:00
1.50 SURFAC, DRILL OTHR T Clear dump lines in CPU and transfer
lines to MagTec. SIMOPS process 13-
3/8" casing in the pipe shed.
119.0 119.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 4/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/10/2023
16:00
7/10/2023
16:45
0.75 SURFAC, DRILL TRIP T TIH from 119'-420' MD, SO 106K. 119.0 420.0
7/10/2023
16:45
7/10/2023
17:00
0.25 SURFAC, DRILL SRVY P Cycle pumps and obtain gyro survey. 420.0 420.0
7/10/2023
17:00
7/10/2023
18:00
1.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 420'-
472' MD, 472' TVD.
650 gpm; 1090 psi; 30% FO
40 rpm; Tq on 3-7K; off 1-2K
WOB 10-25K
PU 107K; SO 107K; ROT 107K
ADT .56; AST .46; Bit hrs 4.54; Jar hrs.
1.13
420.0 472.0
7/10/2023
18:00
7/11/2023
00:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 472'-
837' MD, 823' TVD. Pump 40 bbls anti-
bit balling sweeps every other stand.
700 gpm; 1100 psi; 43% FO
40 rpm; Tq on 2-4K; off 1-2K
WOB 10-25K
PU 120K; SO 116K; ROT 119K
ADT 3.62; AST 2.33; Bit hrs 8.16; Jar
hrs. 4.75
472.0 837.0
7/11/2023
00:00
7/11/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 837'-
1370' MD, 1245' TVD. Pump 40 bbls
anti-bit balling sweeps every 3rd stand.
650 gpm; 1150 psi; 30% FO
40 rpm; Tq on 4K; off 1-2K
WOB 15-30K
PU 130K; SO 121K; ROT 126K
ADT 3.98; AST 2.59; Bit hrs 12.14; Jar
hrs. 8.73
837.0 1,370.0
7/11/2023
06:00
7/11/2023
09:30
3.50 SURFAC, DRILL DDRL P Drill 16" surface hole section from 1370'-
1760' MD, 1696' TVD. Pump 40 bbls
anti-bit balling sweeps every 3rd stand.
800 gpm; 17600 psi; 20-40% FO
50 rpm; Tq on 7-10K; off 1-5K
WOB 10-35K
PU 131K; SO 126K; ROT 128K
ADT 1.92; AST .39; Bit hrs 14.06; Jar
hrs. 10.65
1,370.0 1,760.0
7/11/2023
09:30
7/11/2023
10:45
1.25 SURFAC, DRILL CIRC T Circulate bottoms up from 1760'-1666'
MD, 600 gpm, 880 psi, PU 135-147K.
Grind & inject on CD1 shut down due to
pad being shut down by Operations.
1,760.0 1,666.0
7/11/2023
10:45
7/11/2023
11:15
0.50 SURFAC, DRILL OWFF T Monitor well for 30 minutes, static. 1,666.0 1,666.0
7/11/2023
11:15
7/11/2023
11:45
0.50 SURFAC, DRILL REAM T Wash & ream in the hole from 1666'-
1760' MD, 78 gpm, 110 psi, 50 rpm, Tq
1-6K, ROT SO 137K.
CD1 & grind / inject opened up to
resume cuttings disposal.
1,666.0 1,760.0
7/11/2023
11:45
7/11/2023
18:00
6.25 SURFAC, DRILL DDRL P Drill 16" surface hole section from 1760'-
2125' MD, 1996' TVD. Pump 40 bbls
anti-bit balling sweeps as needed.
1124 gpm; 2640 psi; 35% FO
60 rpm; Tq on 3-7K; off 1-5K
WOB 28-40K
PU 137K; SO 135K; ROT 138K
ADT 3.31; AST .8; Bit hrs 18.42; Jar hrs.
15.01
1,760.0 2,125.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 5/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/11/2023
18:00
7/12/2023
00:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole section from 2125'-
2409' MD, 2127' TVD. Pump 40 bbls
anti-bit balling sweeps as needed.
1170 gpm; 2640 psi; 35% FO
55 rpm; Tq on 3-7K; off 1-5K
WOB 28-40K
PU 139K; SO 135K; ROT 141K
ADT 4.83; AST .02; Bit hrs 23.43; Jar
hrs. 20.02
2,125.0 2,409.0
7/12/2023
00:00
7/12/2023
06:15
6.25 SURFAC, DRILL DDRL P Drill 16" surface hole section from 2409'-
2728' MD, 2400' TVD. Pump 40 bbls
anti-bit balling sweeps as needed.
1150 gpm; 2750 psi; 35% FO
55 rpm; Tq on 4-8K; off 1-3K
WOB 10-18K
PU 141K; SO 135K; ROT 144K
ADT 4.65; AST .77; Bit hrs 28.07; Jar
hrs. 24.66
2,409.0 2,728.0
7/12/2023
06:15
7/12/2023
06:30
0.25 SURFAC, TRIPCAS SRVY P Obtain final MWD & gyro surveys. 2,728.0 2,728.0
7/12/2023
06:30
7/12/2023
07:30
1.00 SURFAC, TRIPCAS CIRC P Circulate bottoms up 2 times, racking
back a stand for each from 2728'-2591'
MD.
1000 gpm; 2150 psi; FO 40%
80 rpm; Tq 2-5K
PU-ROT 129K; ROT 125K
2,728.0 2,591.0
7/12/2023
07:30
7/12/2023
08:00
0.50 SURFAC, TRIPCAS OWFF P Monitor well 30 minutes, static. 2,591.0 2,591.0
7/12/2023
08:00
7/12/2023
12:00
4.00 SURFAC, TRIPCAS BKRM P Backream out of the hole from 2591'-
1665' MD.
1000 gpm; 2150 psi; FO 40%
60 rpm; Tq 3-5K
400-600 fph
PU-ROT 129K; ROT 125K
2,591.0 1,665.0
7/12/2023
12:00
7/12/2023
13:15
1.25 SURFAC, TRIPCAS BKRM P Backream out of the hole from 1665'-
1482' MD.
1000 gpm; 2150 psi; FO 40%
60 rpm; Tq 3-5K
200-500 fph
PU-ROT 126K; ROT 124K
1,665.0 1,482.0
7/12/2023
13:15
7/12/2023
15:15
2.00 SURFAC, TRIPCAS PMPO P Pump out of the hole from 1482'-460'
MD, 600 gpm, 827 psi, PU 107K.
1,482.0 460.0
7/12/2023
15:15
7/12/2023
18:30
3.25 SURFAC, TRIPCAS PMPO P Pump out of the hole from 460'-181' MD,
200 gpm, 140 psi, PU 97K.
460.0 181.0
7/12/2023
18:30
7/12/2023
19:00
0.50 SURFAC, TRIPCAS OWFF P Monitor well 30 minutes, static. 181.0 181.0
7/12/2023
19:00
7/12/2023
22:00
3.00 SURFAC, TRIPCAS BHAH P Lay down 16" surface BHA as per SLB
DD to surface. SIMOPS mobilize casing
equipment to rig floor when able.
181.0 0.0
7/12/2023
22:00
7/13/2023
00:00
2.00 SURFAC, CASING RURD P Rig up to run surface casing. Hang strap
tongs; make up CRT & cement swivel to
top drive; install spiders in rotary table;
hang bail extensions & elevators.
0.0 0.0
7/13/2023
00:00
7/13/2023
03:45
3.75 SURFAC, CASING PUTB P PJSM, Run 13-3/8", 68#, L80, H563
shoe track as per tally. All connections
BakerLok & torqued to 30K up to the pin
end of joint #4. Continue running casing
as per tally to 695' MD. Connections
torqued to 25K, double bumped with
BOL 2000 on threads. Fill casing on the
fly and top off every 10 joints. PU 122K,
SO 95K.
0.0 695.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 6/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/13/2023
03:45
7/13/2023
07:45
4.00 SURFAC, CASING PUTB P Run 13-3/8", 68#, L80, H563 casing;
working past obstructions as needed
from 695'-849' MD. Use varying
parameters of pump rate and string
weight to pass through. 2-5.5 bpm, 40-
95 psi, PU 122-130K, SO 84-121K.
695.0 849.0
7/13/2023
07:45
7/13/2023
09:00
1.25 SURFAC, CASING PUTB P Run 13-3/8", 68#, L80, H563 casing
from 849'-1280' MD. Connections torque
to 25K, double bumped with BOL 2000
on threads. Fill casing on the fly and top
off every 10 joints. PU 141K, SO 123K.
849.0 1,280.0
7/13/2023
09:00
7/13/2023
09:45
0.75 SURFAC, CASING CIRC P Circulate bottoms up staging up the
pump rate to 7 bpm, 79 psi, PU 145K,
SO 138K.
1,280.0 1,280.0
7/13/2023
09:45
7/13/2023
12:00
2.25 SURFAC, CASING PUTB P Run 13-3/8", 68#, L80, H563 casing
from 1280'-2187' MD. Connections
torque to 25K, double bumped with BOL
2000 on threads. Fill casing on the fly
and top off every 10 joints. PU 195K,
SO 166K.
1,280.0 2,187.0
7/13/2023
12:00
7/13/2023
14:00
2.00 SURFAC, CASING PUTB P Run 13-3/8", 68#, L80, H563 casing
from 2187'-2661' MD. Connections
torque to 25K, double bumped with BOL
2000 on threads. Fill casing on the fly
and top off every 10 joints. PU 224K,
SO 174K.
2,187.0 2,661.0
7/13/2023
14:00
7/13/2023
15:00
1.00 SURFAC, CASING HOSO P Make up FMC hanger & landing joint
sections, run in the hole & land hanger
on depth at 2721' MD, 2396' TVD. PU
224K, SO 174K.
2,661.0 2,721.0
7/13/2023
15:00
7/13/2023
18:30
3.50 SURFAC, CEMENT CIRC P Circulate & condition mud for cementing
job. Stage up pumps to 7.5 bpm, 152
psi, FO 13-18%. Rig up cementing line
& circulate at 5 bpm, 193 psi, FO 9-
13%. Hold PJSM for cementing.
2,721.0 2,721.0
7/13/2023
18:30
7/13/2023
22:45
4.25 SURFAC, CEMENT CMNT P Pump surface cement job as per SLB
program. Pump 5 bbls of water. Test
lines to 3500 psi, good. Pump 100 bbls
of 10.8 ppg spacer at 5 bpm, 100-87 psi.
Batch lead cement. Load bottom plug.
Pump 377 bbls of 11.0 ppg lead cement
at 5.5 bpm, 189-222 psi. Tail cement wet
20:56. Batch & pump 72 bbls of 15.8
ppg tail cement at 6 bpm, 492-552 psi.
Mud Push to surface at 51bbls into tail.
Load top plug. Pump 20 bbls of water at
4.5 bpm, 306 psi. Swap to rig pump and
displace cement with 376 bbls of 10.5
ppg mud at 6 bpm, 394-698 psi & 3
bpm, 450 psi. Cement to surface at
35bbls into displacement. Plug bump
with 376 bbls pumped and pressured up
to 1000 psi, held for 5 minutes. Check
floats, good. CIP 22:50 hrs. Lost returns
with 335 bbls of mud pumped on
displacement. Total losses during
cementing 42 bbls. Check floats, good.
2,721.0 0.0
7/13/2023
22:45
7/14/2023
00:00
1.25 SURFAC, CEMENT RURD P Flush riser & surface equipment with
black water pill. Drain surface riser & top
rinse. Back out landing joint & lay down
2 piece landing joint.
0.0 0.0
7/14/2023
00:00
7/14/2023
01:30
1.50 SURFAC, CEMENT RURD P Finish rigging down casing equipment &
CRT as per DDI Casing Rep. Clean
CPU and pits from surface cement job.
Clean rig floor & BOP deck.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 7/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/14/2023
01:30
7/14/2023
03:45
2.25 SURFAC, CEMENT NUND P Prep rig floor & BOP deck to lay down
surface risers. Nipple down surface
risers & surface adapter. Clean out
cement & gravel from hanger flutes to 4"
outlets.
Cement level 27" down from surface
hanger.
0.0 0.0
7/14/2023
03:45
7/14/2023
04:30
0.75 SURFAC, CEMENT NUND P Install FMC wellhead as per rep.
SIMOPS clean cement valves, mud pits,
shakers, flow box, & CPU tank from
cement job.
0.0 0.0
7/14/2023
04:30
7/14/2023
06:45
2.25 SURFAC, WHDBOP NUND P Orient wellhead & flow line tie in . Rig up
18-3/4" high pressure riser & stage for
nipple up of BOPE. SIMOPS wait for
CPAI pad operator to verify orientation.
RKB to upper lock down screws 49.60';
lower lock down screws 52.01' MD.
0.0 0.0
7/14/2023
06:45
7/14/2023
07:00
0.25 SURFAC, WHDBOP NUND P Orientation verified by CPAI pad
operator. Set high pressure riser on
wellhead & secure.
0.0 0.0
7/14/2023
07:00
7/14/2023
07:15
0.25 SURFAC, WHDBOP PRTS P FMC Rep. rig up and test wellhead
seals to 1000 psi for 10 minutes, CPAI
Drilling Supervisor witness.
0.0 4.8
7/14/2023
07:15
7/14/2023
12:00
4.75 SURFAC, WHDBOP NUND P Nipple up 18-3/4" BOP stack. Hook up
kill & choke lines. Hook up MPD lines.
Center & secure BOP stack. Install OA
valves. Install pitcher nipple & air boots.
Load test joints in the pipe shed. Obtain
RKBs for BOPE.
0.0 0.0
7/14/2023
12:00
7/14/2023
13:00
1.00 SURFAC, WHDBOP NUND P Torque flanges on kill & choke lines.
Torque flanges on OA & IA valves.
Inflate air boots on pitcher nipple.
0.0 0.0
7/14/2023
13:00
7/14/2023
14:30
1.50 SURFAC, WHDBOP RURD P Make up 4-1/2" & 5-7/8" floor valves for
testing. Mobilize test pups & test plug to
the rig floor. Make up 4-1/2" test joint &
set test plug per FMC.
0.0 0.0
7/14/2023
14:30
7/14/2023
15:45
1.25 SURFAC, WHDBOP SEQP P Perform NOV break in procedure on
lower, new 4-1/2" X 7-5/8" VBRs with 4-
1/2" test joint. Remove 4-1/2" test joint &
install 7-5/8" test joint. Perform
procedure, function rams open & close 5
times on each size.
0.0 0.0
7/14/2023
15:45
7/14/2023
17:30
1.75 SURFAC, WHDBOP RURD P Blow down top drive. Rig up test
equipment. Flood lines with water &
purge air from system.
0.0 0.0
7/14/2023
17:30
7/15/2023
00:00
6.50 SURFAC, WHDBOP BOPE P Perform BOP test with 7-5/8" test joint.
All tests 250 psi low / 5,000 psi high
(initial test); 5 minutes each test -
annular tested to 250 / 2500 psi, upper 4
-1/2" x 7-5/8" VBR's, lower 4-1/2" x 7-
5/8" VBR's, blind/shear rams, CM #1-16,
manual choke and kill, HCR choke and
kill, kill valve #3, upper / lower IBOP, 5-
7/8" FOSV and dart valve, 4-1/2" FOSV
and dart valve. Manual & super chokes
tested to 1500 psi with controlled bleed
off. Perform accumulator drawdown test.
Witnessed by AOGCC Rep. Brian Bixby
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 8/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/15/2023
00:00
7/15/2023
03:30
3.50 SURFAC, WHDBOP BOPE P Continue test BOPE to 250 psi / 5000
psi, annular 250 / 3500 psi with the 4-
1/2" test joint for 5 minutes each test.
Test annular, upper VBR 4-1/2" X 7-5/8",
& lower VBR 4-1/2" X 7-5/8". 2 fail /
pass for the test; manual choke was
greased & functioned, retested good; &
upper VBRs with 4-1/2" test joint was
functioned several times & retested
good. AOGCC Representative Brian
Bixby witnessed test.
0.0 0.0
7/15/2023
03:30
7/15/2023
04:45
1.25 SURFAC, WHDBOP RURD P Pull 4-1/2" test joint & change out
elevators. Make up stand of DP to MPD
test plug. Drain MPD riser. Set MPD test
plug.
0.0 0.0
7/15/2023
04:45
7/15/2023
05:15
0.50 SURFAC, WHDBOP MPDA P Fluid pack MPD equipment & mud
cross. Pressure test to 250 psi / 1200
psi for 5 minutes each test, charted.
0.0 0.0
7/15/2023
05:15
7/15/2023
06:30
1.25 SURFAC, WHDBOP RURD P Pull MPD test plug & rig down
equipment. Remove FMC test plug.
Drain stack & blow down all lines. Install
FMC wear bushing. Run in lock down
screws per FMC Rep. Lay down 4-1/2"
test joints and space out pups.
0.0 0.0
7/15/2023
06:30
7/15/2023
06:45
0.25 SURFAC, WHDBOP RURD P Fill stack with mud, close blinds & purge
air from system for casing pressure test.
0.0 0.0
7/15/2023
06:45
7/15/2023
07:30
0.75 SURFAC, WHDBOP PRTS P Test 13-3/8" surface casing for 30
minutes, charted. Pressure up to 2771
psi with 4.75 bbls shut in & monitor
pressure. Final pressure after 30
minutes 2720 psi. Bled back 4.75 bbls.
0.0 0.0
7/15/2023
07:30
7/15/2023
07:45
0.25 SURFAC, WHDBOP RURD P Open blind / shear rams. Rig down test
equipment.
0.0 0.0
7/15/2023
07:45
7/15/2023
09:00
1.25 SURFAC, WHDBOP RURD P Remove trip nipple. Change out lower
air boots. Install trip nipple. Fill riser &
check for leaks, good.
0.0 0.0
7/15/2023
09:00
7/15/2023
12:30
3.50 SURFAC, DRILLOUT BHAH P Pick up 12-1/4" Intermediate 1, BHA 2
as per SLB DD & MWD from surface to
440' MD.
0.0 440.0
7/15/2023
12:30
7/15/2023
14:00
1.50 SURFAC, DRILLOUT TRIP P Trip in the hole from 440'-2387' MD on 5
-7/8" DP.
440.0 2,387.0
7/15/2023
14:00
7/15/2023
14:30
0.50 SURFAC, DRILLOUT DHEQ P Fill drill pipe and shallow hole test MWD
at 700 gpm, 850 psi. Tools tested good.
2,387.0 2,387.0
7/15/2023
14:30
7/15/2023
16:00
1.50 SURFAC, DRILLOUT REAM P Wash & ream in the hole from 2387'-
2630' MD.
700 gpm, 850 psi
30 rpm, Tq 4K
200 fph
PU 153K, SO 131K, ROT 141K
Obtain slow circulating rates.
2,387.0 2,630.0
7/15/2023
16:00
7/15/2023
18:30
2.50 SURFAC, DRILLOUT DRLG P Drill out cement plugs & float collar from
2630'-2632' MD as per SLB DD.
650 gpm, 740 psi
30-50 rpm, Tq 4-12K
WOB 2-12K
2,630.0 2,632.0
7/15/2023
18:30
7/15/2023
22:00
3.50 SURFAC, DRILLOUT DRLG P Drill out cement in shoe track from
2632'-2717' MD. Contaminated cement
observed at the shakers. SIMOPS treat
cement returns in the pits.
700 gpm, 840 psi
30-80 rpm, Tq 4-12K
WOB 2-5K
2,632.0 2,717.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 9/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/15/2023
22:00
7/16/2023
00:00
2.00 SURFAC, DRILLOUT DRLG P Drill shoe from 2717'-2719' MD as per
SLB DD. SIMOPS treat cement returns
in the pits.
700 gpm, 840 psi
30-80 rpm, Tq 4-12K
WOB 1-4K
ROT 146K
2,717.0 2,719.0
7/16/2023
00:00
7/16/2023
02:45
2.75 SURFAC, DRILLOUT DRLG P Drill shoe & rat hole from 2719'-2728'
MD as per SLB DD.
700 gpm, 840 psi
30-80 rpm, Tq 4-12K
WOB 1-4K
ROT 146K
2,719.0 2,728.0
7/16/2023
02:45
7/16/2023
03:15
0.50 SURFAC, DRILLOUT DDRL P Drill 12-1/4' intermediate section from
2728'-2748' MD, 2413' TVD
700 gpm, 840 psi, FO 37%
40-90 rpm, Tq on 6-12K, off 4-7K
WOB 5K
ECD 10.65
PU 157K, SO 131K, ROT 147K
ADT .5; BIT .5; JARS 25.16 hrs.
2,728.0 2,748.0
7/16/2023
03:15
7/16/2023
04:00
0.75 SURFAC, DRILLOUT CIRC P Circulate bottoms up reciprocating
2748'-2696' MD.
800 gpm, 1065 psi, FO 37%
40 rpm, Tq 4-7K
2,748.0 2,696.0
7/16/2023
04:00
7/16/2023
05:15
1.25 SURFAC, DRILLOUT LOT P Perform LOT at the shoe, 2721' MD,
2396' TVD with 10.5 ppg DrilPlex mud.
Pressure up 981 psi at 1/2 bpm with 2.6
bbl pumped. Shut in and record
pressures for 10 minutes, with a final
pressure of 441 psi. LOP picked at 909
psi for an 17.8 ppg EMW.
2,696.0 2,696.0
7/16/2023
05:15
7/16/2023
07:00
1.75 INTRM1, DRILL CIRC P Circulate LOT data up from MWD tools.
Continue circulating while data is
discussed with town.
800 gpm, 1065 psi, FO 38%
Obtain slow circulating rates.
2,696.0 2,696.0
7/16/2023
07:00
7/16/2023
08:30
1.50 INTRM1, DRILL DISP P Displace well to 10.8 ppg FWP system
as per plan. Pump 50 bbls Hi-Vis
spacer, followed with new 10.8 ppg
FWP. Bit was on bottom as new mud
came out of the bit. Circulated 410 bbls
to see clean FWP at surface. Send
downlinks per DD. Obtain slow
circulating rates.
500 gpm, 419 psi
30 rpm, Tq 3K
PUROT 142K, SOROT139K
2,696.0 2,748.0
7/16/2023
08:30
7/16/2023
12:00
3.50 INTRM1, DRILL DDRL P Drill 12-1/4' intermediate section from
2748'-2967' MD, 2538' TVD. Obtain
torque & drag every 5 stands. Pump
sweeps every other stand.
1000 gpm, 1460 psi, FO 38%
140 rpm, Tq on 7K, off 4K
WOB 4K
ECD 11.11
PU 157K, SO 131K, ROT 144K
ADT 2.66; BIT 3.16; JARS 27.82 hrs.
2,748.0 2,967.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 10/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/16/2023
12:00
7/16/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4' intermediate section from
2967'-3398' MD, 2753' TVD. Obtain
torque & drag every 5 stands. Pump
sweeps every other stand.
1000 gpm, 1510 psi, FO 38%
140 rpm, Tq on 6K, off 5K
WOB 6K
ECD 11.1
PU 149K, SO 144K, ROT 146K
ADT 4.85; BIT 8.01; JARS 32.67 hrs.
2,967.0 3,398.0
7/16/2023
18:00
7/17/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4' intermediate section with
NOVOS from 3398'-3789' MD, 2899'
TVD. Obtain torque & drag every 5
stands. Pump sweeps every other
stand.
1000 gpm, 1580 psi, FO 41%
150 rpm, Tq on 5K, off 2-4K
WOB 5K
ECD 11.21
PU 153K, SO 145K, ROT 150K
ADT 4.49; BIT 12.5; JARS 37.16 hrs.
3,398.0 3,789.0
7/17/2023
00:00
7/17/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4' intermediate section with
NOVOS from 3789'-4245' MD, 2989'
TVD. Obtain torque & drag every 5
stands. Pump sweeps every other
stand.Obtain slow circulating rates.
1000 gpm, 1720 psi, FO 41%
140 rpm, Tq on 8K, off 5K
WOB 5-7K
ECD 11.43
PU 155K, SO 141K, ROT 146K
ADT 4.78; BIT 17.28; JARS 41.94 hrs.
3,789.0 4,245.0
7/17/2023
06:00
7/17/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4' intermediate section from
4245'-4742' MD, 3062' TVD. Obtain
torque & drag every 5 stands. Pump
sweeps every other stand. Started
adding PHPA to mud system ~4505'MD,
mud system had 1ppb of PHPA ~4735'
MD.
1000 gpm, 1800 psi, FO 40%
160 rpm, Tq on 9K, off 6K
WOB 9K
ECD 11.68
PU 161K, SO 139K, ROT 145K
ADT 4.95; BIT 22.23; JARS 46.89 hrs.
4,245.0 4,742.0
7/17/2023
12:00
7/17/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4' intermediate section from
4742'-5215' MD, 3119' TVD. Obtain
torque & drag every 5 stands. Pump
sweeps every other stand. Obtain slow
circulating rates.
1000 gpm, 1919 psi, FO 39%
160 rpm, Tq on 10K, off 6K
WOB 11K
ECD 11.78
PU 161K, SO 139K, ROT 145K
ADT 4.55; BIT 26.78; JARS 51.44 hrs.
4,742.0 5,215.0
7/17/2023
18:00
7/17/2023
20:30
2.50 INTRM1, DRILL DDRL P Drill 12-1/4' intermediate section with
NOVOS from 5215'-5444' MD, 3146'
TVD. Obtain torque & drag every 5
stands. Pump sweeps every other
stand.
1000 gpm, 1970 psi, FO 37%
160 rpm, Tq on 11K, off 6K
WOB 11K
ECD 11.94
PU 162K, SO 136K, ROT 150K
ADT 2.01; BIT 28.79; JARS 53.45 hrs.
5,215.0 5,444.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 11/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/17/2023
20:30
7/18/2023
00:00
3.50 INTRM1, DRILL CIRC T Observe pack off at 5444' MD before
making a connection. Observed 200 psi
increase and recorded MWD data
showed ECD spike from 12.01 to 16.23
ppg EMW. Stage out of the hole from
5444'-5121' MD to get above pack off
zone. Pump 50 bbls 35 ppb LCM pill @
22:15 hrs.
25-100 gpm, 323-415 psi, no returns
60-90 rpm, Tq 8-16K
ROT143K
5,444.0 5,121.0
7/18/2023
00:00
7/18/2023
06:00
6.00 INTRM1, DRILL BKRM T Stage out of the hole from 5121'-4598'
MD to get above pack off zone. Pump
50 bbls 35 ppb LCM pill @ 02:20 hrs.
25-50 gpm, 370-705 psi, no returns
60-90 rpm, Tq 8-16K
ROT143K
5,121.0 4,598.0
7/18/2023
06:00
7/18/2023
12:00
6.00 INTRM1, DRILL BKRM T Stage out of the hole from 4598'-4413'
MD to get above pack off zone.
25-75 gpm, 328-519 psi, no returns
40-160 rpm, Tq 16-32K
ROT143K
4,598.0 4,413.0
7/18/2023
12:00
7/18/2023
15:45
3.75 INTRM1, DRILL REAM T Stage in the hole from 4413'-4607' MD,
to try to establish circulation, increasing
rpm and flow rates. No returns.
60-225 gpm, 340-550 psi
40-180 rpm, Tq 15K
PU ROT 144, SO ROT 133K, ROT 143K
4,413.0 4,607.0
7/18/2023
15:45
7/18/2023
16:00
0.25 INTRM1, DRILL OWFF T Monitor well for 15 minutes, static. 4,607.0 4,607.0
7/18/2023
16:00
7/18/2023
17:00
1.00 INTRM1, DRILL MPDA T Install 5-7/8" MPD bearing as per MPD
advisor. Circulate through MPD system.
PU 182K, SO 84K, ROT 144K (Pump
off)
4,607.0 4,607.0
7/18/2023
17:00
7/18/2023
21:45
4.75 INTRM1, DRILL BKRM T Stage out the hole from 4607'-4330' MD
with low energy back ream. No returns.
At 4330' MD observe return from drill
pipe. Monitor flow to no flow to allow
wellbore to relax.
25 gpm, 250-270 psi
10 rpm, Tq 10-21K
PU ROT 148K, SO ROT 126K, ROT
138K
4,607.0 4,330.0
7/18/2023
21:45
7/19/2023
00:00
2.25 INTRM1, DRILL TRIP T Trip out of the hole from 4330'-4117'
MD. Stepped up pickup weight
incrementally to observe break over at
237K. Free travel at 231K. Circulate
across the top through MPD system
monitoring Coriolis.
PU 231-207K, SO 84K, ROT 138K.
4,330.0 4,117.0
7/19/2023
00:00
7/19/2023
00:45
0.75 INTRM1, DRILL TRIP T Work pipe up F/4,117' T/4,015' with no
rotary or pump, 119K PUW, 138K RTW,
monitor G/L / hole fill with MPD
4,117.0 4,015.0
7/19/2023
00:45
7/19/2023
01:00
0.25 INTRM1, DRILL CIRC T Attempt to est circ w/ 25 GPM, 307 PSI,
50 GPM, 323 PSI, 75 GPM, 340 PSI.
191K-200K PUW, 138K RTW. 10 RPM,
16K TQ. No success.
4,015.0 4,015.0
7/19/2023
01:00
7/19/2023
06:00
5.00 INTRM1, DRILL TRIP T POOH F/ 4,015' T/3,461' MD. No rotary
or pump. 197K-208K PUW. Monitor
G/L / hole fill with MPD
4,015.0 3,461.0
7/19/2023
06:00
7/19/2023
12:00
6.00 INTRM1, DRILL TRIP T POOH F/ 3,461' T/2,864' MD. No rotary
or pump. 20K Overpull, slack off, rotate
10 RPM, 19K TQ, bringing BHA into
casing to 2,658'. 185K PUW. 139K
RTW. Monitor G/L / hole fill with MPD
3,461.0 2,705.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 12/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/19/2023
12:00
7/19/2023
17:15
5.25 INTRM1, DRILL CIRC T Reciprocate pipe inside shoe F/ 2,658'
T/ 2,705' MD to establish circulation.
100 RPM, 18K TQ. 40 GPM, 300 PSI,
No returns. Rot/Recip w/ no pumps at
30 RPM 4X up/down. Stage up flow rate
F/ 10-60 GPM maintaining 310 PSI.
Observed pressure drop and return flow
out. Good returns. Continue to stage up
flow rate in 100 GPM increments T/ 650
GPM, 770 PSI. 30 RPM, 2K TQ.
2,705.0 2,705.0
7/19/2023
17:15
7/19/2023
18:15
1.00 INTRM1, DRILL MPDA T Flow check, PJSM, Rack back stand in
Drk. Pull 5-7/8" MPD bearing/Element
per MPD advisor.
2,705.0 2,705.0
7/19/2023
18:15
7/19/2023
19:45
1.50 INTRM1, DRILL CIRC T Circ 2X BU & recip F/ 2,705' T/ 2,565'
MD. 600-1000 GPM, 1200 PSI, 47%
FO, Lots of mushy clay. Pump NP/SAPP
sweep, some increase in clay.
2,705.0 2,705.0
7/19/2023
19:45
7/19/2023
21:15
1.50 INTRM1, DRILL OWFF T Flow check, well breathing back at
dimishing rates.
2,705.0 2,705.0
7/19/2023
21:15
7/20/2023
00:00
2.75 INTRM1, DRILL BKRM T BROOH F/ 2,705' T/ 1,830' MD. 1000
GPM, 1410 PSI, 44% FO, 40 RPM, 2-
6K TQ, Observed lots of mushy clay on
shakers w/ BR.
2,705.0 1,830.0
7/20/2023
00:00
7/20/2023
03:15
3.25 INTRM1, DRILL BKRM T BROOH F/ 1,830' T/ 439' MD. 1000
GPM, 1400 PSI, 44% FO, 40 RPM, 2-
6K TQ, Pumped 50 Bbl NP/SAPP
sweep @ 30° inc. Increase in clay with
some hard clay also. Pumped another at
20° inc with very lttle increase in clay.
1,830.0 439.0
7/20/2023
03:15
7/20/2023
03:45
0.50 INTRM1, DRILL OWFF T OWFF, static, 15 min. PJSM on LD BHA 439.0 439.0
7/20/2023
03:45
7/20/2023
06:00
2.25 INTRM1, DRILL BHAH T POOH on elevators to bit. Inspect all
BHA components. Monitor hole fill on
TT.
439.0 0.0
7/20/2023
06:00
7/20/2023
06:30
0.50 INTRM1, DRILL BHAH T Clean off BHA, clean and clear floor. 0.0 0.0
7/20/2023
06:30
7/20/2023
08:30
2.00 INTRM1, DRILL BHAH T PJSM, MU BHA #3, 5-7/8" HWDP and
jars T/ 412'
0.0 412.0
7/20/2023
08:30
7/20/2023
10:00
1.50 INTRM1, DRILL TRIP T RIH W/ BHA #3 on 5-7/8" DP F/ Drk. F/
412' T/ 2,638' MD. Monitor displacement
on pit #5. 114K SOW.
412.0 2,638.0
7/20/2023
10:00
7/20/2023
10:45
0.75 INTRM1, DRILL CIRC T Fill pipe, shallow hole test tools,
downlink per DD. 850 GPM, 1200 PSI.
140K PUW, 137K SOW, 138K RTW.
2,638.0 2,638.0
7/20/2023
10:45
7/20/2023
12:00
1.25 INTRM1, DRILL REAM T Ream in hole F/ 2,638' T/ shoe. 1000
GPM, 1615 PSI, 40 RPM, Observe take
wt and pressure spike at 2,721'. PU and
slow rotary to 20 RPM, Continue work
bit outside shoe, increase to 70 RPM
once cleaned up. Cont ream in hole T/
2,918' MD. 1000 GPM, 1670 PSI, 37%
FO, 70 RPM, 6K TQ.
2,638.0 2,918.0
7/20/2023
12:00
7/20/2023
18:00
6.00 INTRM1, DRILL REAM T Ream in hole F/ 2,918' T/ 4,852' MD.
1000 GPM, 1950 PSI, 39% FO, 100
RPM, 8K TQ.
2,918.0 4,852.0
7/20/2023
18:00
7/20/2023
20:45
2.75 INTRM1, DRILL REAM T Ream in hole F/ 4,852' T/ 5,444' MD.
1000 GPM, 1980 PSI, 39% FO, 100
RPM, 8K TQ.
4,852.0 5,444.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 13/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/20/2023
20:45
7/21/2023
00:00
3.25 INTRM1, DRILL DDRL P Drill 12-1/4" Int #1 W/ NOVOS F/ 5,444'
T/5,616 MD. 3,166' TVD. Obtain T&D
every 5 stds, pump bit balling sweeps
every other stand. 1080 GPM. (Limited
by Xcel TRPM) 2265 PSI, 44% FO, 160
RPM, 9K TQ on, 4K TQ off, 9K WOB,
11.64 ECD, Max gas 53 units. 157K
PUW, 136K SOW, 147K RTW.
ADT=2.66, Bit hrs=31.45, Jar hrs=56.11.
5,444.0 5,616.0
7/21/2023
00:00
7/21/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int #1 W/ NOVOS F/ 5,616'
T/6,030 MD. 3,214' TVD. Obtain T&D
every 5 stds, pump bit balling sweeps
every other stand. 1080 GPM. (Limited
by Xcel TRPM) 2380 PSI, 45% FO, 175
RPM, 9K TQ on, 6K TQ off, 4K WOB,
11.74 ECD, Max gas 53 units. 158K
PUW, 137K SOW, 147K RTW.
ADT=4.89, Bit hrs=36.34, Jar hrs=
61.00.
5,616.0 6,030.0
7/21/2023
06:00
7/21/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int #1 W/ NOVOS F/ 6,030'
T/ 6,514 MD. 3,271' TVD. Obtain T&D
every 5 stds, pump bit balling sweeps
every other stand. 1080 GPM. (Limited
by Xcel TRPM) 2448 PSI, 45% FO, 175
RPM, 11K TQ on, 7K TQ off, 7K WOB,
11.78 ECD, Max gas 14 units. 159K
PUW, 138K SOW, 144K RTW.
ADT=4.76, Bit hrs=41.10, Jar hrs=65.76
6,030.0 6,514.0
7/21/2023
12:00
7/21/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int #1 W/ NOVOS F/ 6,514'
T/ 6,970 MD. 3,327' TVD. Obtain T&D
every 5 stds, pump bit balling sweeps
every other stand. 1061 GPM. (Limited
by Xcel TRPM) 2538 PSI, 40% FO, 175
RPM, 11K TQ on, 10K TQ off, 8K WOB,
11.77 ECD, Max gas 33 units. 162K
PUW, 139K SOW, 149K RTW.
ADT=4.87, Bit hrs=45.97, Jar hrs=70.63
6,514.0 6,970.0
7/21/2023
18:00
7/22/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int #1 W/ NOVOS F/ 6,970'
T/ 7,400 MD. 3,383' TVD. Obtain T&D
every 5 stds, pump bit balling sweeps
every other stand. 1060 GPM. (Limited
by Xcel TRPM) 2607 PSI, 40% FO, 175
RPM, 13K TQ on, 9K TQ off, 7K WOB,
11.77 ECD, Max gas 45 units. 167K
PUW, 136K SOW, 147K RTW.
ADT=4.44, Bit hrs=50.41, Jar hrs=75.07
6,970.0 7,400.0
7/22/2023
00:00
7/22/2023
05:30
5.50 INTRM1, DRILL DDRL P Drill 12-1/4" Int #1 W/ NOVOS F/ 7,400'
T/ 7,811 MD. 3,433' TVD. Obtain T&D
every 5 stds, pump bit balling sweeps
every other stand. 1060 GPM. (Limited
by Xcel TRPM) 2607 PSI, 40% FO, 175
RPM, 13K TQ on, 9K TQ off, 7K WOB,
11.77 ECD, Max gas 45 units. 167K
PUW, 136K SOW, 147K RTW.
ADT=4.30, Bit hrs=54.71, Jar hrs=79.37
Section TD called 7,811' MD 3,433'
TVD.
7,400.0 7,811.0
7/22/2023
05:30
7/22/2023
06:45
1.25 INTRM1, TRIPCAS CIRC P Circulate while rotate and reciprocate
from 7,810' MD to 7,734' MD 1060
GPM , 2660 PSI, 40% FO, 175 RPM, 8K
TQ, 11.86 ECD.
Total pumped 15,500 strokes.
7,811.0 7,811.0
7/22/2023
06:45
7/22/2023
07:00
0.25 INTRM1, TRIPCAS CIRC P Obtain final SPR's and torque and drag
readings at 7,811' MD Mud weight 10.8
ppg.
PUW=168K, SOW=142K, RW=151K.
7,811.0 7,811.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 14/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/22/2023
07:00
7/22/2023
07:15
0.25 INTRM1, TRIPCAS BKRM P Backream from 7,811 MD to 7,736' MD
1060 GPM, 2630 PSI, 175 RPM. 8K TQ,
142K RW.
7,811.0 7,736.0
7/22/2023
07:15
7/22/2023
08:00
0.75 INTRM1, TRIPCAS OWFF P Perform flow check and verify well
static, service top drive.
7,736.0 7,736.0
7/22/2023
08:00
7/22/2023
12:00
4.00 INTRM1, TRIPCAS BKRM P Pump 50 bbl nut plug sweep and
backream out of the hole from 7,736'
MD to 6,682' MD
1060 GPM, 2500 PSI, 150 RPM. 8K TQ,
142K RW.
7,736.0 6,682.0
7/22/2023
12:00
7/22/2023
18:00
6.00 INTRM1, TRIPCAS BKRM P Backream out of the hole from 6,682'
MD to 4,763' MD
1060 GPM, 2308 PSI, 120 RPM. 8K TQ,
138K RW.
6,682.0 4,763.0
7/22/2023
18:00
7/23/2023
00:00
6.00 INTRM1, TRIPCAS BKRM P Backream out of the hole from 4,763'
MD to 3,102' MD
1060 GPM, 2069 PSI, 120 RPM. 6-8K
TQ, 152K PUW, 135K SOW, 141K RW.
4,763.0 3,102.0
7/23/2023
00:00
7/23/2023
06:00
6.00 INTRM1, TRIPCAS BKRM P Backream out of hole from 3,102' MD to
1,700' MD.
1060 GPM, 1834 PSI, 100 RPM. 6-8K
TQ, 142K PUW, 125K SOW, 134K RW.
Pump bit balling sweep at 2271' 13-3/8"
casing shoe.
3,102.0 1,700.0
7/23/2023
06:00
7/23/2023
06:30
0.50 INTRM1, TRIPCAS CIRC P Circulate and reciprocate from 1,700'
MD to 1,610' MD , pump not plug
sweep, shakers clean at 4200 strokes
pumped.
1060 GPM, 1842 PSI, 100 RPM. 3K TQ,
1,700.0 1,700.0
7/23/2023
06:30
7/23/2023
06:45
0.25 INTRM1, TRIPCAS OWFF P Perform flow check well static.
Clean and clear rig floor.
1,700.0 1,700.0
7/23/2023
06:45
7/23/2023
07:30
0.75 INTRM1, TRIPCAS TRIP P POOH from 1,700' MD to 131' MD
monitoring hole fill via trip tank. L/D 3
joints HWDP to pipeshed.
1,700.0 131.0
7/23/2023
07:30
7/23/2023
09:00
1.50 INTRM1, TRIPCAS BHAH P L/D BHA as per SLB Rep from 131' MD
to surface.
131.0 0.0
7/23/2023
09:00
7/23/2023
10:00
1.00 INTRM1, CASING WWWH P M/U stack washer and wash BOP stack
at max rate. Function all rams and
annular as per SOP.
0.0 0.0
7/23/2023
10:00
7/23/2023
11:15
1.25 INTRM1, CASING RURD P Drain BOP, B/D kill line and close blind
ram. C/O upper rams to 9-5/8" solid
body rams. M/U 9-5/8" test joints and
pups.
0.0 0.0
7/23/2023
11:15
7/23/2023
12:00
0.75 INTRM1, CASING MPSP P Pull wear ring and set test plug as per
FMC Rep.
0.0 0.0
7/23/2023
12:00
7/23/2023
13:00
1.00 INTRM1, CASING BOPE P Fill BOP with fresh water and flood
surface lines. Conduct shell test.
Test upper solid body rams to 250 PSI
low for 5 minutes and 3500 PSI high for
5 minutes.
0.0 0.0
7/23/2023
13:00
7/23/2023
13:30
0.50 INTRM1, CASING MPSP P Pull test plug as per FMC Rep.
L/D test joint and pups. Drain BOP.
0.0 0.0
7/23/2023
13:30
7/23/2023
15:30
2.00 INTRM1, CASING RURD P PU 9-5/8" Landing Jt, pup and mandrel
hanger as per FMC Rep. Perform
dummy run. SIMOPS: Mobilize DDI
casing equip, RU Volant and casing
handling tools.
0.0 0.0
7/23/2023
15:30
7/23/2023
16:30
1.00 INTRM1, CASING PUTB P PJSM, MU shoe track, Bakerlock Jts 1-
4. Fill pipe and test floats per Co Man.
0.0 160.0
7/23/2023
16:30
7/23/2023
18:00
1.50 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing
per tally. F/ 160' T/440' MD. 16K MUT, 9-
5/8" X 12-1/4" centralizer on each Jt,
filling each Jt on the fly, topping off
every 10 Jts.
160.0 440.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 15/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/23/2023
18:00
7/23/2023
23:45
5.75 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing
per tally. F/ 440' T/2,699' MD. 16K MUT,
9-5/8" X 12-1/4" centralizer on Jts #4-
#49, filling each Jt on the fly, topping off
every 10 Jts.
440.0 2,699.0
7/23/2023
23:45
7/24/2023
00:00
0.25 INTRM1, CASING CIRC P Fill pipe, CBU staging up pump rate to 8
BPM, 150 PSI. SIMOPS: Install new 2"
cement hose.
2,699.0 2,699.0
7/24/2023
00:00
7/24/2023
01:30
1.50 INTRM1, CASING CIRC P CBU staging up flow rate to 336 GPM
150 PSI. Total 2000 strokes pumped.
Install 2" cement hose and pressure test
to 5000 psi.
At shoe, PUW=171K, SOW = 160K,
RTW = 166K
2,699.0 2,699.0
7/24/2023
01:30
7/24/2023
06:00
4.50 INTRM1, CASING PUTB P RIH with 9-5/8" 47# T95, H563 casing
from 2,669' MD to 4,900' MD M/U TQ
16K, filling pipe on the fly and topping
off every 10 joints. SOW=155K
2,699.0 4,900.0
7/24/2023
06:00
7/24/2023
11:30
5.50 INTRM1, CASING PUTB P RIH with 9-5/8" 47# T95, H563 casing
from 4,900' MD to 7,744' MD M/U TQ
16K, filling pipe on the fly and topping
off every 10 joints. SOW=171K
4,900.0 7,744.0
7/24/2023
11:30
7/24/2023
12:00
0.50 INTRM1, CASING PUTB P M/U FMC tubing hanger, Landing joint
and pup. RIH fro 7,744' to 7,800.89'
SOW=167K, PUW=230K. Land hanger
and set down 73K.
7,744.0 7,800.9
7/24/2023
12:00
7/24/2023
14:45
2.75 INTRM1, CEMENT CIRC P Circulate and condition mud staging up
rate F/ 3 BPM, 190 PSI T/ 6 BPM, 210
PSI. 15% FO, 5562 stks total
7,800.9 7,800.9
7/24/2023
14:45
7/24/2023
16:15
1.50 INTRM1, CEMENT CIRC P RU cement line, continue circ and
condition at 6 BPM, 367 PSI W/ PJSM
W/ crew on cementing, 7,900 stks total.
7,800.9 7,800.9
7/24/2023
16:15
7/24/2023
18:00
1.75 INTRM1, CEMENT CMNT P SLB PT lines to 4000 PSI, Pump 73.7
bbls 12.0 PPG mud push at 3.5 BPM,
drop bottom plug, SLB pump 168.1 bbls
15.8 PPG cement at 5.4 BPM, 234-147
PSI, drop top plug, SLB pump 20 bbls
H2O.
7,800.9 7,800.9
7/24/2023
18:00
7/24/2023
19:45
1.75 INTRM1, CEMENT CMNT P Displace cement w/ 10.8 ppg mud at 6
BPM, slow to 3 BPM 15 bbls prior to btm
plug landing on FC, observed plug land
and rupture disc on calculated stks, inc
rate back to 6 BPM, reduce flow rate to
4.7 then 3.0 BPM 26 bbls from calc
bump. Top plug bumped on schedule at
4656 stks. CIP at 19:26 Hrs. Bump plug
with 500 psi over final disp pressure to
890 PSI, hold 5 min, bleed off check
floats ok. Full returns, no losses
throughout job.
7,800.9 7,800.9
7/24/2023
19:45
7/24/2023
21:00
1.25 INTRM1, CEMENT PRTS P RU and test 9-5/8" casing T/ 3850 PSI
for 30 min, charted. 66 stks pumped.
7,800.9 7,800.9
7/24/2023
21:00
7/24/2023
23:30
2.50 INTRM1, CEMENT RURD P RD circ equip, back out landing Jt, RD
Volant and casing equipment,
7,800.9 7,800.9
7/24/2023
23:30
7/25/2023
00:00
0.50 INTRM1, CEMENT WWSP P PU std 5-7/8" HWDP, MU FMC running
tool, drain stack, observed lots of clay
above hanger, stack wont drain all the
way.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 16/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/25/2023
00:00
7/25/2023
04:00
4.00 INTRM1, CEMENT WWSP T Unable to drain stack through OA line
packed solids/clay. Pump through OA
valve taking returns to pits, 8 BPM, 78
PSI, attempt to drain stack , unable to
drain stack. Connect air to OA and blow
through, attempt to drain stack, blow air
and water drain through OA and IA at
the same time as flushing with air and
water. Attempt to run FMC packoff as
per FMC rep. Unable to set packoff, pull
out of hole , pack off covered in clay.
Rinse and blow through OA and IA to
rinse clay and clean profile. RIH with
pack off and set verify seat with FMC
rep. Run in lock down screws and test
pack off to 5000 psi for 10 minutes. R/D
running tool and flush cement lines.
0.0 0.0
7/25/2023
04:00
7/25/2023
06:00
2.00 INTRM1, WHDBOP RURD P R/U 4-1/2" test joint and FMC test plug.
RIH and set test plug. R/U BOP testing
equipment on the rig floor. SIMOPS
clean and inspect the lower VBR rams.
0.0 0.0
7/25/2023
06:00
7/25/2023
07:00
1.00 INTRM1, WHDBOP RURD P Remove upper 9-5/8" solid body rams
and install 4-1/2" x 7-5/8" VBR rams.
0.0 0.0
7/25/2023
07:00
7/25/2023
08:30
1.50 INTRM1, WHDBOP SEQP P Fill stack and conduct shell test. 0.0 0.0
7/25/2023
08:30
7/25/2023
14:00
5.50 INTRM1, WHDBOP BOPE P Perform full BOP test witness waived by
Sully Sullivan, AOGCC, all test 250 low
psi and 3850 high psi for 5 minutes
charted with the exception of annular
tested to 250 psi low and 2500 psi high
for 5 minutes with 4-1/2 " test jt and the
manual operated and super chokes
tested to 250 psi low and 2000 psi high
for 5 charted minutes. Test conducted
wit 4-1/2" and 7-5/8" test joints in
annular , upper and lower VBR's. Test
choke valves #1-16, manual operated,
super choke, kill manuals, HCR and 4"
valve on kill line. 4-1/2" and 5-7/8"
FOSV, 4-1/2" and 5-7/8" dart valve,
upper and lower IBOP and blind shear
rams.
Perform Koomey test and test PVT, flow
out, LEL and H2S alarms.
Simops, freeze protect 13-3/8" x 9-5/8"
OA pump 90 Bbls of diesel at average 2
BPM, Max pressure observed 584 PSI
at 89 bbls pumped.
0.0 0.0
7/25/2023
14:00
7/25/2023
15:00
1.00 INTRM1, WHDBOP MPSP P Pull test plug and drain BOP blow down
surface lines and choke manifold. Set
wear ring as per FMC rep,
OD: 13.42", ID:8.66", Legnth:12.5". L/D
test joint and pups.
0.0 0.0
7/25/2023
15:00
7/25/2023
16:00
1.00 INTRM1, DRILLOUT BHAH P Mobilize BHA #4 components and clean
and clear rig floor.
0.0 0.0
7/25/2023
16:00
7/25/2023
18:00
2.00 INTRM1, DRILLOUT BHAH P PJSM, MU BHA #4 per SLB Rep, RIH F/
0' T/ 174'. Load source. 86K SOW,
monitor displacement on TT.
0.0 174.0
7/25/2023
18:00
7/25/2023
19:30
1.50 INTRM1, DRILLOUT BHAH P MU BHA #4 per SLB Rep, F/ 174' T/
390'. 93K SOW, monitor displacement
on TT.
174.0 390.0
7/25/2023
19:30
7/25/2023
22:15
2.75 INTRM1, DRILLOUT PULD P Single in hole with 4-1/2" DP from shed
F/ 390' T/ 2,024' MD. monitor
displacement on TT. Shallow hole test
MWD, 600 GPM, 1992 PSI, 30% FO,
110K PUW, 100K SOW.
390.0 2,024.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 17/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/25/2023
22:15
7/26/2023
00:00
1.75 INTRM1, DRILLOUT PULD P Single in hole with 4-1/2" DP from shed
F/ 2,024' T/ 3,495' MD. monitor
displacement on TT, 120K PUW, 106K
SOW.
2,024.0 3,495.0
7/26/2023
00:00
7/26/2023
02:00
2.00 INTRM1, DRILLOUT PUTB P Single in hole with 4-1/2" DP from shed
F/ 3,495' T/ 5,765' MD. monitor
displacement on TT, 120K PUW, 106K
SOW.
3,495.0 5,765.0
7/26/2023
02:00
7/26/2023
04:00
2.00 INTRM1, DRILLOUT TRIP P Trip in hole F/5,765' T/ 7,437' w/ 5-7/8"
DP from derrick. monitor displacement
on TT. 122K PUW, 115K SOW.
5,765.0 7,437.0
7/26/2023
04:00
7/26/2023
05:00
1.00 INTRM1, DRILLOUT REAM P Precautionary ream F/ 7,437' to float
collar at 7,708' MD. 550 GPM, 2600
PSI, 26% FO, 120K RTW
7,437.0 7,708.0
7/26/2023
05:00
7/26/2023
06:00
1.00 INTRM1, DRILLOUT DRLG P Drill plugs and float collar F/ 7,708' T/
7,711' MD per DD. 550 GPM, 2640 PSI,
28% FO, 15-17K WOB, 50 RPM, 11K
TQ, 121K RTW
7,708.0 7,711.0
7/26/2023
06:00
7/26/2023
08:00
2.00 INTRM1, DRILLOUT DRLG P Drill cement F/ 7,711' T/7,798' MD. 550
GPM, 2590 PSI, 28% FO, 60 RPM, 14K
TQ
7,711.0 7,798.0
7/26/2023
08:00
7/26/2023
09:00
1.00 INTRM1, DRILLOUT CIRC P Tag top of shoe at 7,798' MD, Circ hole
clean, 700 GPM, 3820 PSI, 75 RPM,
12K TQ, 35% FO
7,798.0 7,798.0
7/26/2023
09:00
7/26/2023
09:30
0.50 INTRM1, DRILLOUT DRLG P Drill shoe and rathole F/ 7,798' T/ 7,811'
w/ low WOB. 600 GPM, 2870 PSI, 60
RPM, 13K TQ, 27% FO.
7,798.0 7,811.0
7/26/2023
09:30
7/26/2023
10:30
1.00 INTRM1, DRILLOUT REAM P Ream shoe 3X, 168K PUW, 91K SOW,
135K RTW
7,811.0 7,811.0
7/26/2023
10:30
7/26/2023
11:30
1.00 INTRM1, DRILLOUT DDRL P Directionaly drill 8-1/2" Int 2 hole F/
7,811' T/ 7,831' MD, 3,436' TVD. 700
GPM, 3688 PSI, 37% FO, 80 RPM, 15K
TQ on, 11K TQ off, 3-5K WOB, 12.22
ECD, 168K PUW, 91K SOW, 131K
RTW. ADT = .42, Bit Hrs = .42, Total bit
Hrs = 54.68, Jar Hrs = 79.79
7,811.0 7,831.0
7/26/2023
11:30
7/26/2023
13:30
2.00 INTRM1, DRILLOUT CIRC P Circ and condition mud for FIT. 700
GPM, 3719 PSI, 80 RPM, 11K TQ, 38%
FO, 12.3 ECD, 10.7 MW
7,831.0 7,831.0
7/26/2023
13:30
7/26/2023
14:15
0.75 INTRM1, DRILLOUT LOT P Perform FIT. Pumped 2.7 bbls with 10.7
ppg mud, Leaked off at 474 psi, 13.4
EMW, shut in and record pressures 10
min with 321 psi final pressure, bled
back 2.3 bbls.
7,831.0 7,831.0
7/26/2023
14:15
7/26/2023
15:00
0.75 INTRM2, DRILL MPDA P Flow check, install 5-7/8" RCD
element/bearing per SOP
7,831.0 7,831.0
7/26/2023
15:00
7/26/2023
15:45
0.75 INTRM2, DRILL DISP P Prep pits for displacement, PJSM 7,831.0 7,831.0
7/26/2023
15:45
7/26/2023
16:45
1.00 INTRM2, DRILL DISP P Displace well to 9.0 PPG FWP per plan,
700 GPM, 2500 PSI, 60 RPM, 6K TQ,
38% FO, 5500 stks total. 80 bbls
interface. 162K PUW, 102K SOW, 137K
RTW, 2K TQ
7,831.0 7,831.0
7/26/2023
16:45
7/26/2023
18:00
1.25 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" Int 2 hole F/
7,831' T/ 7,890' MD, 3,444' TVD. 700
GPM, 2442 PSI, 26% FO, 100 RPM, 9K
TQ on, 2K TQ off, 12K WOB, 10.93
ECD, 168K PUW, 102K SOW, 135K
RTW. ADT = .70, Bit Hrs = 1.12, Total bit
Hrs = 55.38, Jar Hrs = 80.49
7,831.0 7,890.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 18/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/26/2023
18:00
7/26/2023
18:45
0.75 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" Int 2 hole F/
7,890' T/ 7,970' MD, 3,452' TVD. 700
GPM, 2462 PSI, 26% FO, 100 RPM, 8K
TQ on, 2K TQ off, 6-9K WOB, 10.93
ECD, 155K PUW, 109K SOW, 137K
RTW. ADT = .75, Bit Hrs = 1.87, Total bit
Hrs = 56.13, Jar Hrs = 81.24
7,890.0 7,970.0
7/26/2023
18:45
7/26/2023
20:15
1.50 INTRM2, DRILL CIRC P BROOH F/7,970' T/ 7,958' MD, Obtain
baseline values at 700 GPM, 2450 PSI,
4490 TRPM, 60 RPM, 4-6K TQ, 148K
PUW, 113K SOW, 137K RTW, break
connection and drop 1.25" ball, Pump
250 GPM for first 200 Stks, 720 PSI,
reduce rate to 100 GPM, 520 PSI, 30
RPM, ball on seat at 593 stks, 1565 PSI
shear pressure, Increase pump rate to
compare against baseline, 700 GPM,
2114 PSI, 4070 TRPM, 60 RPM, 5-7K
TQ, Appears UR opened. Ream down
F/ 7,958' T/ 7,962' MD, backream to
7,936' to place UR 2' below shoe. Stop
rotary, pull to 7,932' to pull UR against
shoe with 10K. Confirmed UR open.
Ream down to 7,970'.
7,970.0 7,970.0
7/26/2023
20:15
7/27/2023
00:00
3.75 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 7,970' T/ 8,258' MD, 3,487' TVD.
700 GPM, 2169 PSI, 26% FO, 150
RPM, 9K TQ on, 6K TQ off, 6K WOB,
11.1 ECD, 155K PUW, 109K SOW,
137K RTW. ADT = 2.81, Bit Hrs = 4.68,
Total bit Hrs = 58.94, Jar Hrs = 84.05.
Pump bit balling sweeps every other
stand.
7,970.0 8,258.0
7/27/2023
00:00
7/27/2023
06:00
6.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" Int 2 hole F/
8,258' T/ 8,732' MD, 3,544' TVD with
MPD. 700 GPM, 2225 PSI, 29% FO,
150 RPM, 10K TQ on, 6K TQ off, 9K
WOB, 11.2 ECD, 160K PUW, 112K
SOW, 141K RTW. ADT = 3.98, Bit Hrs =
8.66, Total bit Hrs = 62.92, Jar Hrs =
88.03. Pump bit balling sweeps every
other stand.
8,258.0 8,732.0
7/27/2023
06:00
7/27/2023
07:30
1.50 INTRM2, DRILL CIRC P Circulate and reciprocate due to high
ECD. 700 GPM, 2240 PSI, 110 RPM,
7K TQ, 28% FO
8,732.0 8,732.0
7/27/2023
07:30
7/27/2023
12:00
4.50 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 8,732' T/ 9,105' MD, 3,590' TVD
with MPD. 700 GPM, 2351 PSI, 28%
FO, 150 RPM, 11K TQ on, 6K TQ off,
8K WOB, 11.32 ECD, 166K PUW, 114K
SOW, 144K RTW. ADT = 3.95, Bit Hrs =
12.61, Total bit Hrs = 66.87, Jar Hrs =
91.98. Pump bit balling sweeps every
other stand.
8,732.0 9,105.0
7/27/2023
12:00
7/27/2023
21:00
9.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 9,105' T/ 9,800' MD, 3,675' TVD
with MPD. 700 GPM, 2356 PSI, 30%
FO, 150 RPM, 10K TQ on, 7K TQ off,
6K WOB, 11.62 ECD, 167K PUW, 116K
SOW, 139K RTW. ADT = 6.1, Bit Hrs =
18.71, Total bit Hrs = 72.97, Jar Hrs =
98.08. Pump bit balling sweeps every
other stand.
9,105.0 9,800.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 19/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/27/2023
21:00
7/28/2023
00:00
3.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 9,800' T/ 10,032' MD, 3,704'
TVD with MPD and NOVOS. 700 GPM,
2530 PSI, 30% FO, 150 RPM, 10K TQ
on, 7K TQ off, 6K WOB, 11.4 ECD,
166K PUW, 120K SOW, 144K RTW.
ADT = 2.0, Bit Hrs = 20.71, Total bit Hrs
= 74.97, Jar Hrs = 100.08. Pump bit
balling sweeps every other stand.
9,800.0 10,032.0
7/28/2023
00:00
7/28/2023
06:00
6.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 10,032' T/ 10,500' MD, 3,760'
TVD with MPD and NOVOS. 700 GPM,
2664 PSI, 30% FO, 150 RPM, 11K TQ
on, 7K TQ off, 8K WOB, 11.9 ECD,
171K PUW, 119K SOW, 147K RTW.
ADT = 4.0, Bit Hrs = 24.71, Total bit Hrs
= 78.97, Jar Hrs = 104.08. Pump bit
balling sweeps every other stand.
10,032.0 10,500.0
7/28/2023
06:00
7/28/2023
12:00
6.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 10,500' T/ 10,964' MD, 3,817'
TVD with MPD and NOVOS. 700 GPM,
2800 PSI, 30% FO, 150 RPM, 10K TQ
on, 8K TQ off, 10K WOB, 12.1 ECD,
170K PUW, 118K SOW, 146K RTW.
ADT = 3.91, Bit Hrs = 28.62, Total bit
Hrs = 82.88, Jar Hrs = 107.99. Pump bit
balling sweeps every other stand.
10,500.0 10,964.0
7/28/2023
12:00
7/28/2023
18:00
6.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 10,964' T/ 11,423' MD, 3,873'
TVD with MPD and NOVOS. 700 GPM,
2800 PSI, 35% FO, 150 RPM, 10K TQ
on, 8K TQ off, 4-10K WOB, 11.95 ECD,
174K PUW, 116K SOW, 147K RTW.
ADT = 4.28, Bit Hrs = 32.90, Total bit
Hrs = 87.16, Jar Hrs = 112.27. Pump bit
balling sweeps every other stand.
10,964.0 11,423.0
7/28/2023
18:00
7/28/2023
21:00
3.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 11,423' T/ 11,699' MD, 3,908'
TVD with MPD and NOVOS. 700 GPM,
2830 PSI, 35% FO, 150 RPM, 10K TQ
on, 8K TQ off, 5-10K WOB, 12.08 ECD,
176K PUW, 115K SOW, 147K RTW.
ADT = 2.32, Bit Hrs = 35.22, Total bit
Hrs = 89.48, Jar Hrs = 114.59. Pump bit
balling sweeps every other stand.
11,423.0 11,699.0
7/28/2023
21:00
7/29/2023
00:00
3.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 11,699' T/ 11,912' MD, 3,935'
TVD with MPD and NOVOS. 700 GPM,
2865 PSI, 30% FO, 150 RPM, 11K TQ
on, 7K TQ off, 11K WOB, 12.1 ECD,
171K PUW, 116K SOW, 148K RTW.
ADT = 1.76, Bit Hrs = 36.98, Total bit
Hrs = 91.24, Jar Hrs = 116.35. Pump bit
balling sweeps every other stand.
11,699.0 11,912.0
7/29/2023
00:00
7/29/2023
06:00
6.00 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 11,912' T/ 12,401' MD, 3,995'
TVD with MPD and NOVOS. 700 GPM,
2904 PSI, 30% FO, 150 RPM, 14K TQ
on, 10K TQ off, 7K WOB, 12.3 ECD,
180K PUW, 112K SOW, 148K RTW.
ADT = 4.09, Bit Hrs = 41.07, Total bit
Hrs = 95.33, Jar Hrs = 120.44. Pump bit
balling sweeps every other stand.
11,912.0 12,401.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 20/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/29/2023
06:00
7/29/2023
11:30
5.50 INTRM2, DRILL DDRL P Directionaly drill 8-1/2" x 9-1/2" Int 2
hole F/ 12,401' T/ 12,825' MD, 4,057'
TVD to TD with MPD and NOVOS. 700
GPM, 2800 PSI, 32% FO, 150 RPM,
11K TQ on, 6K TQ off, 6K WOB, 11.95
ECD, 186K PUW, 118K SOW, 153K
RTW. ADT = 3.7, Bit Hrs = 44.77, Total
bit Hrs = 99.03, Jar Hrs = 124.14. Pump
bit balling sweeps every other stand.
12,401.0 12,825.0
7/29/2023
11:30
7/29/2023
12:00
0.50 INTRM2, TRIPCAS CIRC P Obtain final survey, T&D, pre reamer
closing parameters. 700 GPM, 2790
PSI, 100 RPM, 6-11K TQ, 4070 TRPM.
186K PUW, 118K SOW, 143K RTW
12,825.0 12,825.0
7/29/2023
12:00
7/29/2023
12:30
0.50 INTRM2, TRIPCAS CIRC P Drop 1-5/8" UR closing ball, 245 GPM,
917 PSI for 750 stks, slow to 100 GPM,
725 PSI, ball on seat 1118 stks, reamer
indexed closed with 2300 PSI.
12,825.0 12,825.0
7/29/2023
12:30
7/29/2023
12:45
0.25 INTRM2, TRIPCAS CIRC P Obtain comparison parameters. 700
GPM, 3050 PSI, 100 RPM, 7-10K TQ,
4420 TRPM. Appears UR closed.
12,825.0 12,825.0
7/29/2023
12:45
7/29/2023
13:00
0.25 INTRM2, TRIPCAS CIRC P LD working single and obtain T&D w/
reamer closed. 186K PUW, 124K SOW,
149K RTW
12,825.0 12,812.0
7/29/2023
13:00
7/29/2023
14:15
1.25 INTRM2, TRIPCAS CIRC P CBU 1.5X w/ BROOH F/ 12,812'
T/12,626'. 700 GPM, 2800 PSI, 140
RPM, 8-10K TQ, 11.7 ECD. 143K RTW
12,812.0 12,626.0
7/29/2023
14:15
7/29/2023
14:30
0.25 INTRM2, TRIPCAS CIRC P Obtain SPR's @ 12,262' MD, 4,050'
TVD. 9.0 PPG MW
#1 MP - 20 SPM-850/448 PSI
30 SPM - 870/405 PSI
#2 MP - 20 SPM - 845/445 PSI
30 SPM-870/404 PSI
12,626.0 12,626.0
7/29/2023
14:30
7/29/2023
16:00
1.50 INTRM2, TRIPCAS BKRM P BROOH F/12,626' T/ 12,254', 700 GPM,
2820 PSI, 120 RPM, 7-10K TQ, 11.78
ECD, 145K RTW. Holding 11.7 EMW on
bottom with MPD
12,626.0 12,254.0
7/29/2023
16:00
7/29/2023
16:45
0.75 INTRM2, TRIPCAS OWFF P OWFF 12,254.0 12,254.0
7/29/2023
16:45
7/29/2023
18:00
1.25 INTRM2, TRIPCAS BKRM P BROOH F/12,254' T/ 11,882', 700 GPM,
2780 PSI, 120 RPM, 7-10K TQ, 11.8
ECD, 143K RTW. Holding 11.7 EMW on
bottom with MPD
12,254.0 11,882.0
7/29/2023
18:00
7/30/2023
00:00
6.00 INTRM2, TRIPCAS BKRM P BROOH F/11,882' T/ 10,255', 700 GPM,
2672 PSI, 140 RPM, 9K TQ, 11.5 ECD,
140K RTW. Holding 11.7 EMW on
bottom with MPD on connections
11,882.0 10,255.0
7/30/2023
00:00
7/30/2023
06:00
6.00 INTRM2, TRIPCAS BKRM P BROOH F/10,255' T/ 8,642', 700 GPM,
2512 PSI, 140 RPM, 7K TQ, 11.09 ECD,
138K RTW. Holding 11.7 EMW on
bottom with MPD on connections
10,255.0 8,642.0
7/30/2023
06:00
7/30/2023
09:45
3.75 INTRM2, TRIPCAS BKRM P BROOH F/8,642' T/ 7,711', 700 GPM,
2480 PSI, 120 RPM, 7-9K TQ, 11.9
ECD, 134K RTW. Holding 11.7 EMW on
bottom with MPD on connections
8,642.0 7,711.0
7/30/2023
09:45
7/30/2023
10:45
1.00 INTRM2, TRIPCAS CIRC P Circulate hole clean with 40 Bbls NP
sweep 2X BU w/ rotate and
reciprocate.700 GPM, 2480 PSI, 7-9K
TQ, 10.84 ECD 134K RTW.
7,711.0 7,711.0
7/30/2023
10:45
7/30/2023
12:30
1.75 INTRM2, TRIPCAS OWFF P Bleed off MPD pressure and monitor
well through 2" in cellar. Drop 2-7/8"
hollow drift on wire on Std #78, blow
down top drive. SIMOPS: tighten shot
pin bolts
7,711.0 7,711.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 21/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/30/2023
12:30
7/30/2023
15:30
3.00 INTRM2, TRIPCAS SMPD P SOOH on elevators F/ 7,711' T/ 5,819'
MD. 135K PUW. Monitor hole fill on pit
#5.
7,711.0 5,819.0
7/30/2023
15:30
7/30/2023
16:00
0.50 INTRM2, TRIPCAS OWFF P Bleed off MPD pressure. Flow check 5,819.0 5,819.0
7/30/2023
16:00
7/30/2023
16:30
0.50 INTRM2, TRIPCAS MPDA P Remove 5-7/8" MPD bearing assy (BA) 5,819.0 5,819.0
7/30/2023
16:30
7/30/2023
16:45
0.25 INTRM2, TRIPCAS TRIP P C/O bushings, POOH on elevators F/
5,819' T/ 5,761' MD and stand back last
stand of 5-7/8" DP
5,819.0 5,761.0
7/30/2023
16:45
7/30/2023
17:15
0.50 INTRM2, TRIPCAS MPDA P Install 4-1/2" MPD BA 5,761.0 5,761.0
7/30/2023
17:15
7/30/2023
17:30
0.25 INTRM2, TRIPCAS RURD P Install stripping rubber and stand under
bushings. C/O elevators T/ 4-1/2". LD 5-
7/8 x 4-1/2 XO
5,761.0 5,761.0
7/30/2023
17:30
7/30/2023
18:00
0.50 INTRM2, TRIPCAS SMPD P SOOH on elevators F/ 5,761' T/ 5,383'
MD. 130K PUW. Monitor hole fill on pit
#5.
5,761.0 5,383.0
7/30/2023
18:00
7/30/2023
22:30
4.50 INTRM2, TRIPCAS SMPD P SOOH on elevators F/ 5,383' T/ 485'
MD. 100K PUW. Monitor hole fill on pit
#5.
5,383.0 485.0
7/30/2023
22:30
7/31/2023
00:00
1.50 INTRM2, TRIPCAS OWFF P Monitor well for flow. SIMOPS: Prep for
MPD BA removal, Clean floor.
485.0 485.0
7/31/2023
00:00
7/31/2023
00:30
0.50 INTRM2, TRIPCAS OWFF P Monitor well for flow. Static, 30 min.
SIMOPS: Prep for MPD BA removal,
Clean floor.
485.0 485.0
7/31/2023
00:30
7/31/2023
01:00
0.50 INTRM2, TRIPCAS MPDA P Pull 4-1/2" MPD bearing assy (BA), rack
back last std of 4-1/2" DP
485.0 390.0
7/31/2023
01:00
7/31/2023
04:45
3.75 INTRM2, TRIPCAS BHAH P PJSM, LD BHA #4 F/ 390' T/ 110' per
SLB DD, monitor hole on TT.
390.0 110.0
7/31/2023
04:45
7/31/2023
05:00
0.25 INTRM2, TRIPCAS BHAH P PJSM, clear floor and areas of
personnel, remove SLB nuclear source
per DD/MWD
110.0 110.0
7/31/2023
05:00
7/31/2023
06:15
1.25 INTRM2, TRIPCAS BHAH P LD BHA #4 F/ 110' T/ 0' per SLB DD,
monitor hole on TT.
110.0 0.0
7/31/2023
06:15
7/31/2023
07:00
0.75 INTRM2, TRIPCAS BHAH P Clear and clean floor. Change out
elevators to 5-7/8"
0.0 0.0
7/31/2023
07:00
7/31/2023
08:00
1.00 INTRM2, CASING WWWH P MU stack washer T/ std 5-7/8" DP and
wash stack. Break off stack washer,
rack std 5-7/8" DP.
Off highline power and on generator
power per Alp Ops request at 0715 hrs.
0.0 0.0
7/31/2023
08:00
7/31/2023
09:00
1.00 INTRM2, CASING RURD P RU 7-5/8" liner equipment, safety valve
XO and fill up line
0.0 0.0
7/31/2023
09:00
7/31/2023
10:30
1.50 INTRM2, CASING PUTB P PJSM, MU 7-5/8", 29.7#, L80, H523
liner shoe track T/ 333'. Backerlock Jts
#1-#7, TQ to 12K.
0.0 333.0
7/31/2023
10:30
7/31/2023
11:30
1.00 INTRM2, CASING PUTB P Fill pipe w/ fill up line. MU XO and pump
in sub and cement line, circ through
shoe track at 1 BPM. Check floats.
(Take on OBM to pits)
333.0 333.0
7/31/2023
11:30
7/31/2023
11:45
0.25 INTRM2, CASING RURD P RD Cement line and remove XO 333.0 333.0
7/31/2023
11:45
7/31/2023
12:30
0.75 INTRM2, CASING PUTB P RIH w/ 7-5/8", 39#, P110S, H523 F/ 333'
T/ 796' MD. TQ to 17K, Monitor
displacement on pit #5. Fill pipe every
10 Jts. 86K SOW
333.0 796.0
7/31/2023
12:30
7/31/2023
14:15
1.75 INTRM2, CASING PUTB P RIH @ 30 FPM, W/ 7-5/8", 29.7#, L80,
H523 liner F/ 796' T/ 1,696' MD. TQ to
12K, Monitor displacement on pit #5. Fill
pipe every 10 Jts. 146K PUW, 86K
SOW
796.0 1,696.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 22/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/31/2023
14:15
7/31/2023
14:45
0.50 INTRM2, CASING MPDA P RD Csg tongs, MU XO, PJSM on
installing 7-5/8" MPD BA,
1,696.0 1,696.0
7/31/2023
14:45
7/31/2023
16:00
1.25 INTRM2, CASING MPDA P RU and install 7-5/8" MPD BA 1,696.0 1,696.0
7/31/2023
16:00
7/31/2023
16:30
0.50 INTRM2, CASING MPDA P Test MPD equip and SO ability w/ back
pressure. Apply 500 psi, lost all slack
off, 250 psi, no slack off, able to apply
40 psi while RIH. Hold 100 psi in slips.
1,696.0 1,696.0
7/31/2023
16:30
7/31/2023
18:00
1.50 INTRM2, CASING PUTB P RIH @ 30 FPM, W/ 7-5/8", 29.7#, L80,
H523 liner F/ 1,696' T/ 2,500' MD. TQ to
12K, Monitor displacement on pit #5. Fill
pipe every 10 Jts. 146K PUW, 83K
SOW. Holding 100-120 in slips, 40-60 w/
RIH
1,696.0 2,500.0
7/31/2023
18:00
7/31/2023
22:45
4.75 INTRM2, CASING PUTB P RIH @ 30 FPM, W/ 7-5/8", 29.7#, L80,
H523 liner F/ 2,500' T/ 5,142' MD. TQ to
12K, Monitor displacement on pit #5. Fill
pipe every 10 Jts. 98K SOW. Holding
~surge on connections with MPD until
11.0 EMW surge reached, then hold
11.0 static and reduce dynamic to 60-40
psi.
2,500.0 5,142.0
7/31/2023
22:45
7/31/2023
23:15
0.50 INTRM2, CASING OWFF P Monitor well for flow. SIMOPS: Prep for
MPD BA removal
5,142.0 5,142.0
7/31/2023
23:15
7/31/2023
23:45
0.50 INTRM2, CASING MPDA P Remove 7-5/8" MPD bearing assy per
MPD advisor. 186K PUW
5,142.0 5,142.0
7/31/2023
23:45
8/1/2023
00:00
0.25 INTRM2, CASING PULD P RIH last Jt of 7-5/8 liner F/ 5,142' T/
5,160' MD. TQ to 12K. Monitor
displacement on pit #5. 89K SOW.
5,142.0 5,160.0
8/1/2023
00:00
8/1/2023
00:45
0.75 INTRM2, CASING RURD P RD 7-5/8" casing equipment, RU T/ PU
Dril-Quip liner hanger assy
5,160.0 5,160.0
8/1/2023
00:45
8/1/2023
01:45
1.00 INTRM2, CASING PUTB P PU Dril-Quip 7-5/8" x 9-5/8" X Pak
expandable liner hanger assy as per Dril
-Quip Rep. MU liner wiper plugs and
stab into liner. RIH F/5,160' T/ 5,160'
MD
5,160.0 5,214.0
8/1/2023
01:45
8/1/2023
03:15
1.50 INTRM2, CASING MPDA P MU 5-7/8" MPD BA on 1st std 5-7/8" DP,
RIH F/ 5,214' T/ 5,262' MD. Set BA as
per MPD Rep. Push/Pull test per MPD,
Break circ to test MPD equip and clear
floats.
5,214.0 5,262.0
8/1/2023
03:15
8/1/2023
06:00
2.75 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
5,262' T/ 6,600' MD. Monitor
displacement on pit #5, Fill pipe on the
fly for weight, top off every 10 stds. 81K
SOW, MDP holding 30 PSI dynamic,
340 PSI static.
5,262.0 6,600.0
8/1/2023
06:00
8/1/2023
06:45
0.75 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
6,600' T/ 7,070' MD. Monitor
displacement on pit #5, Fill pipe on the
fly for weight, top off every 10 stds. 74-
81K SOW, MDP holding 30 PSI
dynamic, 340 PSI static. String floating
through MPD element at tool jts.
6,600.0 7,070.0
8/1/2023
06:45
8/1/2023
07:15
0.50 INTRM2, CASING CIRC P Fill pipe and break circ at 1 BPM, 505
PSI at 7,070' MD
7,070.0 7,070.0
8/1/2023
07:15
8/1/2023
07:30
0.25 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
7,070' T/ 7,158' MD. Monitor
displacement on pit #5, Fill pipe on the
fly for weight, top off every 10 stds. 74-
81K SOW, MDP holding 30 PSI
dynamic, 340 PSI static. String floating
through MPD element at tool jts.
7,070.0 7,158.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 23/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/1/2023
07:30
8/1/2023
10:00
2.50 INTRM2, CASING RUNL P Rotate down at 20 RPM, 5-10K TQ, with
7-5/8" liner on 5-7/8" DP F/ 7,158' T/
7,960' MD. Monitor displacement on pit
#5, Fill pipe on the fly for weight, top off
every 10 stds. 130K RTW, 83-93K SO
RTW, MDP holding 30 PSI dynamic, 340
PSI static.Drift stands out of derrick with
2.75" drift
7,158.0 7,960.0
8/1/2023
10:00
8/1/2023
10:15
0.25 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
7,960' T/ 7,990' MD. 74-83K SOW, MDP
holding 30 PSI dynamic, 340 PSI static.
7,960.0 7,990.0
8/1/2023
10:15
8/1/2023
10:30
0.25 INTRM2, CASING CIRC P Fill pipe and break circ at 1 BPM, 513
PSI at 7,990' MD
7,990.0 7,990.0
8/1/2023
10:30
8/1/2023
12:00
1.50 INTRM2, CASING RUNL P Rotate down at 20 RPM, 7-8K TQ, with
7-5/8" liner on 5-7/8" DP F/ 7,990' T/
8,738' MD. Monitor displacement on pit
#5, Fill pipe on the fly for weight, top off
every 10 stds. 130K RTW, 108-112K SO
RTW, MDP holding 30 PSI dynamic, 340
PSI static.Drift stands out of derrick with
2.75" drift
7,990.0 8,738.0
8/1/2023
12:00
8/1/2023
12:15
0.25 INTRM2, CASING RUNL P Rotate down at 20 RPM, 7-8K TQ, with
7-5/8" liner on 5-7/8" DP F/ 8,738' T/
8,925' MD. Monitor displacement on pit
#5, 130K RTW, 108-112K SO RTW,
MDP holding 30 PSI dynamic, 340 PSI
static.Drift stands out of derrick with
2.75" drift
8,738.0 8,925.0
8/1/2023
12:15
8/1/2023
12:45
0.50 INTRM2, CASING CIRC P Fill pipe and break circ at 1 BPM, 525
PSI at 8,925' MD
8,925.0 8,925.0
8/1/2023
12:45
8/1/2023
13:45
1.00 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
8,925' T/ 9,855' MD. 98-102K SOW,
Monitor displacement on pit #5. MDP
holding 30 PSI dynamic, 340 PSI static.
Drift stands out of derrick with 2.75" drift
8,925.0 9,855.0
8/1/2023
13:45
8/1/2023
14:00
0.25 INTRM2, CASING CIRC P Fill pipe and break circ at 1 BPM, 535
PSI at 9,855' MD
9,855.0 9,855.0
8/1/2023
14:00
8/1/2023
15:15
1.25 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
9,855' T/ 10,780' MD. 101-104K SOW,
Monitor displacement on pit #5. MDP
holding 30 PSI dynamic, 340 PSI static.
Drift stands out of derrick with 2.75" drift
9,855.0 10,780.0
8/1/2023
15:15
8/1/2023
15:30
0.25 INTRM2, CASING CIRC P Fill pipe and break circ at 1 BPM, 546
PSI at 10,780' MD
10,780.0 10,780.0
8/1/2023
15:30
8/1/2023
16:30
1.00 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
10,780' T/ 11,700' MD. 101-104K SOW,
Monitor displacement on pit #5. MDP
holding 30 PSI dynamic, 340 PSI static.
Drift stands out of derrick with 2.75" drift
10,780.0 11,700.0
8/1/2023
16:30
8/1/2023
16:45
0.25 INTRM2, CASING CIRC P Fill pipe and break circ at 1 BPM, 540
PSI at 11,700' MD
11,700.0 11,700.0
8/1/2023
16:45
8/1/2023
17:15
0.50 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
11,700' T/ 11,980' MD. 102-104K SOW,
Monitor displacement on pit #5. MDP
holding 30 PSI dynamic, 340 PSI static.
Drift stands out of derrick with 2.75" drift
11,700.0 11,980.0
8/1/2023
17:15
8/1/2023
17:30
0.25 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" DP F/
11,980' T/ 12,164' MD. 101-108K SOW,
Monitor displacement on pit #5. MDP
holding 30 PSI dynamic, 340 PSI static.
Drift stands out of derrick with 2.75" drift
11,980.0 12,164.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 24/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/1/2023
17:30
8/1/2023
18:00
0.50 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" HWDP
from shed F/ 12,164' T/ 12,422' MD.
Monitor displacement on pit #5. MDP
holding 30 PSI dynamic, 340 PSI static.
Drift stands out of derrick with 2.75" drift
and singles off skate with 2.75" drift.
12,164.0 12,422.0
8/1/2023
18:00
8/1/2023
18:45
0.75 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" HWDP
from shed F/ 12,422' T/ 12,687' MD.
119K SOW. Monitor displacement on pit
#5. MDP holding 30 PSI dynamic, 340
PSI static. Drift singles off skate with
2.75" rabbit.
12,422.0 12,687.0
8/1/2023
18:45
8/1/2023
20:30
1.75 INTRM2, CASING RUNL P RIH with 7-5/8" Liner on 5-7/8" HWDP
from shed F/ 12,687' T/ 12,825' MD. Brk
circ at 1 bpm, 600 PSI w/ RIH. Get
parameters at 12,762' MD, 217K PUW,
118K SOW, 173K RTW, 12K TQ at 30
RPM. PU 15' DP pup and Dbl of DP. Tag
bottom w/o rotary at 12,826' MD.
Monitor displacement on pit #5. MDP
holding 30 PSI dynamic, 340 PSI static.
. Drift singles off skate with 2.75" rabbit
and final std out of derrick.
12,687.0 12,825.0
8/1/2023
20:30
8/1/2023
21:45
1.25 INTRM2, CEMENT CIRC P Circulate and reciprocate, staging up
pump rate F/1 BPM, 826 PSI to 6 BPM,
735 PSI
12,825.0 12,825.0
8/1/2023
21:45
8/2/2023
00:00
2.25 INTRM2, CEMENT CIRC P Begin rotation w/ circulate and
reciprocate F/ 12,780' T/ 12,825' MD.
Stage up flow rate F/ 6 BPM, 780 PSI
T/ 8 BPM, 798 PSI. 12K TQ at 20 RPM.
Shut down pump, prep to PU Citadel
plug head.
12,825.0 12,825.0
8/2/2023
00:00
8/2/2023
01:30
1.50 INTRM2, CEMENT RURD P Pick up Citadel cement head as per
Rep, & get final PU & SO.
PU 237K, SO 134K.
Rig up cement lines / valves & pressure
test to 6500 psi.
12,822.0 12,822.0
8/2/2023
01:30
8/2/2023
02:30
1.00 INTRM2, CEMENT RURD T Citadel hydraulic 3" valve failed to open.
Remove hydraulic valve and rig up
cement hose to cement head. Establish
circulation and check cement lines. Step
rate up to 300 gpm, 780 psi and start
rotation at 20 rpm, Tq 8-12K.
12,822.0 12,822.0
8/2/2023
02:30
8/2/2023
03:00
0.50 INTRM2, CEMENT SFTY P Pre-job safety meeting for cement job. 12,822.0 12,822.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 25/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/2/2023
03:00
8/2/2023
06:00
3.00 INTRM2, CEMENT CMNT P Blow air to cementers and fluid pack
lines. Pressure test cement lines to
4000 psi. SLB batch and pump 40 bbls
of 12.0 ppg mud push at 4 bpm, 515 psi.
Citadel release bottom dart. SLB pump
136 bbls 15.8 ppg class G cement at 4
bpm, 500 - 350 psi. Citadel release top
dart. SLB pump 20 bbl fresh water at 4.5
bpm, 250 psi. Swap to rig mud pump #3.
Displace cement with 9.2 ppg FWP at 4
bpm. At 160 strokes pumped slow rate
to 2 bpm. Latch bottom wiper plug with
235 strokes shear at 840 psi. Increase
rate to 7 bpm. Decrease rate to 2 bpm
at 1500 strokes and latch top wiper plug,
sheared at 1710 psi. Increase rate to 7
bpm. At 2100 strokes shut off pumps
and release BOZO plug. Increase rate
to 7 bpm. At 2400 strokes reduce rate to
2 bpm. Land bottom wiper plug at 2471
strokes, shear at 2498 strokes with 2148
psi. Increase rate to 7 bpm. Slow to 6
bpm at 3297 strokes for ECD control.
Slow to 2 bpm at 3800 strokes. Observe
top wiper land on landing collar at 3834
strokes, FCP 540 psi. Continue pumping
to 1047 psi with 3837 stokes and hold
500 psi over FCP for 5 minutes. Check
floats, holding.
12,822.0 12,822.0
8/2/2023
06:00
8/2/2023
06:30
0.50 INTRM2, CEMENT PACK P Pressure up at 1 bpm to shear liner
hanger shear ring. Noted 3700 psi to
shear. Continue pressuring up to 5000
psi and hold for 5 minutes to expand
power section with 75 strokes pumped.
Liner top at 7639' MD. Bleed off
pressure and confirm hanger set with
65K over pull. Pull to 300K and slack off
to 186K.
12,822.0 12,822.0
8/2/2023
06:30
8/2/2023
08:00
1.50 INTRM2, CEMENT RURD P Blow down cement head and lay down.
Lay down XO and pick up single from
pipeshed.
12,822.0 12,822.0
8/2/2023
08:00
8/2/2023
08:45
0.75 INTRM2, CEMENT PRTS P Slack off to 105K and establish
circulation through kill line. Close
annular and pressure up to test liner top
to 2000 psi. Shut in and hold for 10
minutes.
12,822.0 7,660.0
8/2/2023
08:45
8/2/2023
09:00
0.25 INTRM2, CEMENT PULD P Pick up from 7660'-7624' MD, laying
down 2 singles. PU 192K, SO 152K.
7,660.0 7,624.0
8/2/2023
09:00
8/2/2023
09:30
0.50 INTRM2, CEMENT PACK P Pressure up ball seat to 6150 PSI at 2
BPM to shear ball from seat.
7,624.0 7,624.0
8/2/2023
09:30
8/2/2023
09:45
0.25 INTRM2, CEMENT PULD P Lay down 5-7/8" pup joint. 7,624.0 7,624.0
8/2/2023
09:45
8/2/2023
11:15
1.50 INTRM2, CEMENT MPDA P Remove RCD bearing and flush / blow
down associated lines.
7,624.0 7,624.0
8/2/2023
11:15
8/2/2023
12:15
1.00 INTRM2, CEMENT CIRC P Drop 2 foam balls and pump down to
clean drill pipe. Circulate 2 bottoms up
at 600 gpm, 1150 psi, 20 rpm, Tq 3-5K,
reciprocating, ROT 154K.
7,624.0 7,624.0
8/2/2023
12:15
8/2/2023
12:45
0.50 INTRM2, CEMENT OWFF P Perform 30 minute flow check 7,624.0 7,624.0
8/2/2023
12:45
8/2/2023
13:15
0.50 INTRM2, CEMENT PULD P Trip out of hole from 7624'-7520' MD,
laying singles of heavy weight drill pipe
down to pipeshed.
7,624.0 7,520.0
8/2/2023
13:15
8/2/2023
18:30
5.25 INTRM2, CEMENT TRIP P Trip out of hole from 7520'-50' MD,
racking back 5-7/8" drill pipe in the
derrick.
7,520.0 50.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 26/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/2/2023
18:30
8/2/2023
20:00
1.50 INTRM2, CEMENT PULD P Lay down liner hanger running tool as
per Dril-Quip Rep.
50.0 0.0
8/2/2023
20:00
8/2/2023
20:45
0.75 INTRM2, WHDBOP WWWH P Make up stack washing tool on stand of
5-7/8" drill pipe. Wash stack & wellhead
with 1300 gpm & 10 rpm. Function rams
& annular.
0.0 0.0
8/2/2023
20:45
8/2/2023
22:15
1.50 INTRM2, WHDBOP RURD P Make up FMC running tool to a stand of
5-7/8" DP. Pull wear bushing. Rack back
stand. Make up 4-1/2" test joint & test
plug. Set test plug per FMC Rep.
0.0 0.0
8/2/2023
22:15
8/3/2023
00:00
1.75 INTRM2, WHDBOP RURD P Rig up test equipment on the rig floor.
Fill stack & fluid pack lines with water.
Make up floor valves.
0.0 0.0
8/3/2023
00:00
8/3/2023
00:30
0.50 INTRM2, WHDBOP SVRG P Service top drive, blocks, upper & lower
IBOPs. SIMOPS attempt to shell test
BOP stack.
0.0 0.0
8/3/2023
00:30
8/3/2023
01:30
1.00 INTRM2, WHDBOP BOPE T Trouble shoot & identify leak on shell
test as the annular. Decision made to
move forward with BOP test.
0.0 0.0
8/3/2023
01:30
8/3/2023
08:00
6.50 INTRM2, WHDBOP BOPE P Perform full BOP test, witness waived
by Kam St.John, AOGCC, all test 250
low psi and 3850 high psi for 5 minutes
charted with the exception of annular
tested to 250 psi low and 2500 psi high
for 5 minutes with 4-1/2 " test jt and the
manual operated and super chokes
tested to 250 psi low and 2000 psi high
for 5 charted minutes. Test conducted
wit 4-1/2" and 5-7/8" test joints in upper
and lower VBR's. Test choke valves #1-
16, manual operated, super choke, kill
manuals, HCR and 4" valve on kill line.
4-1/2" and 5-7/8" FOSV, 4-1/2" and 5-
7/8" dart valve, upper and lower IBOP
and blind shear rams.
Perform Koomey test and test PVT, flow
out, LEL and H2S alarms.
Annular failed initial test with 4-1/2" test
joint. It will be changed out and retested.
0.0 0.0
8/3/2023
08:00
8/3/2023
09:00
1.00 INTRM2, WHDBOP RURD T Blow down stack through Kill & Choke
lines. Pull & lay down 5-7/8" test joint.
Close blind rams.
0.0 0.0
8/3/2023
09:00
8/3/2023
10:00
1.00 INTRM2, WHDBOP RURD T Remove sensors from MPD head.
Remove mouse hole & riser.
0.0 0.0
8/3/2023
10:00
8/3/2023
11:00
1.00 INTRM2, WHDBOP RURD T Remove MPD hoses & valves from
MPD head.
0.0 0.0
8/3/2023
11:00
8/3/2023
12:00
1.00 INTRM2, WHDBOP RURD T Remove riser adapter flange from the
MPD head.
0.0 0.0
8/3/2023
12:00
8/3/2023
14:00
2.00 INTRM2, WHDBOP RURD T Remove MPD head & stage on BOP
module floor.
0.0 0.0
8/3/2023
14:00
8/3/2023
16:00
2.00 INTRM2, WHDBOP RGRP T Remove failed Shaffer 18-3/4" annular
element.
0.0 0.0
8/3/2023
16:00
8/3/2023
17:30
1.50 INTRM2, WHDBOP RGRP T Install new 18-3/4" annular element. 0.0 0.0
8/3/2023
17:30
8/3/2023
18:00
0.50 INTRM2, WHDBOP RURD T Install mouse hole. 0.0 0.0
8/3/2023
18:00
8/3/2023
19:45
1.75 INTRM2, WHDBOP RURD T Pick up 4-1/2" test joint & pups. Make
up to test plug. Perform annular break in
procedure as per operating procedure.
Fluid pack lines.
0.0 0.0
8/3/2023
19:45
8/3/2023
20:15
0.50 INTRM2, WHDBOP BOPE T Test annular with 4-1/2" test joint to 250
psi low & 2500 psi high for 5 minutes
each, charted.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 27/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/3/2023
20:15
8/3/2023
21:15
1.00 INTRM2, WHDBOP RURD T Blow down Kill line & Choke manifold.
Pull 4-1/2" test joint. Pull master
bushings.
0.0 0.0
8/3/2023
21:15
8/4/2023
00:00
2.75 INTRM2, WHDBOP RURD T Install MPD RCD head. Install pitcher
nipple. Hook up MPD lines. Torque RCD
head to annular. Torque pitcher nipple to
RCD head.
0.0 0.0
8/4/2023
00:00
8/4/2023
04:30
4.50 INTRM2, WHDBOP RURD T Rig up MPD lines. Torque RCD head to
annular. Torque pitcher nipple to RCD
head. Rig up riser & air boots. Change
out upper air boot on pitcher nipple.
Fluid pack all lines with water. Install
MPD test cap per MPD advisor.
0.0 0.0
8/4/2023
04:30
8/4/2023
05:00
0.50 INTRM2, WHDBOP MPDA T Test MPD Orbit valve to 200 psi for 2
minutes; 1200 psi for 5 minutes. Shell
test all broken connections to 200 psi for
2 minutes; 1200 psi for 5 minutes. All
tests charted. Remove MPD test cap.
0.0 0.0
8/4/2023
05:00
8/4/2023
05:30
0.50 INTRM2, WHDBOP BOPE P Install 4-1/2" test joint. Perform
accumulator drawdown. System initial
pressure 3075 psi; after closure 1720
psi; 200 psi attained in 14 seconds; full
pressure attained in 83 seconds; 10
nitrogen bottles averaged 3950 psi.
Closing response times: annular 16
seconds; upper rams 14 seconds;
blind/shear rams 13 seconds; lower
rams 12 seconds; HCR choke 1 second;
HCR kill 1 second.
0.0 0.0
8/4/2023
05:30
8/4/2023
07:00
1.50 INTRM2, WHDBOP RURD P Pull FMC test plug. Install wear bushing.
Lay down 4-1/2" test joint.
0.0 0.0
8/4/2023
07:00
8/4/2023
07:15
0.25 INTRM2, WHDBOP RURD P Rig up test equipment, flood kill line, &
close blind rams to test casing.
0.0 0.0
8/4/2023
07:15
8/4/2023
08:15
1.00 INTRM2, WHDBOP PRTS P Test 9-5/8" X 7-5/8" casing. Pressured
up at .5 bpm, pumping 11,4 bbls to 3950
psi. Shut in and monitor pressure for 30
minutes. Bled back 11.3 bbls to the trip
tank.
0.0 0.0
8/4/2023
08:15
8/4/2023
08:30
0.25 INTRM2, WHDBOP RURD P Blow down Kill & Choke lines. 0.0 0.0
8/4/2023
08:30
8/4/2023
09:15
0.75 INTRM2, WHDBOP SVRG P Service rig. Pull riser. Install spare air
boot on riser. Install riser, fill riser &
check for leaks.
0.0 0.0
8/4/2023
09:15
8/4/2023
11:30
2.25 INTRM2, DRILLOUT BHAH P Pick up and rack back 1 joint of 4-1/2"
DP, 2 XOs, 2 float subs, Well
Commander, Mudgard, stabilizer,
Pixstar, & stabilizer.
0.0 0.0
8/4/2023
11:30
8/4/2023
14:00
2.50 INTRM2, DRILLOUT BHAH P Make up 6-1/2" bit and production BHA
5 to 215' MD. Install source. Make up
stand with BHA in the derrick & run in
the hole to 276' MD.
0.0 276.0
8/4/2023
14:00
8/4/2023
16:15
2.25 INTRM2, DRILLOUT PULD P Single in the hole from 276'-2157' MD,
60 joints of 4-1/2" DP.
276.0 2,157.0
8/4/2023
16:15
8/4/2023
16:45
0.50 INTRM2, DRILLOUT CIRC P Make up XO & top drive to 4-1/2" string.
Shallow hole test MWD at 220 gpm,
1100 psi, PU 108K, SO 107K.
2,157.0 2,157.0
8/4/2023
16:45
8/4/2023
20:30
3.75 INTRM2, DRILLOUT SLPC P Pick up a single joint of 5-7/8" DP to
space out for cut and slip of drill line.
Hang blocks & pull covers off of
drawworks. Cut and slip 9 wraps, 85' of
drilling line. Change out shot pin bolts.
Unhang blocks & perform block height
calibration. Lay down single joint of 5-
7/8" DP.
2,157.0 2,157.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 28/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/4/2023
20:30
8/5/2023
00:00
3.50 INTRM2, DRILLOUT PULD P Single in the hole from 2157'-5254' MD,
98 joints of 4-1/2" DP. Fill pipe every 20
stands. PU 123K, SO 112K.
2,157.0 5,254.0
8/5/2023
00:00
8/5/2023
03:00
3.00 INTRM2, DRILLOUT PULD P Single in the hole from 5254'-7635' MD,
76 joints of 4-1/2" DP. Fill pipe every 20
stands.
5,254.0 7,635.0
8/5/2023
03:00
8/5/2023
05:00
2.00 INTRM2, DRILLOUT DRLG P Make up a XO & a stand of 5-7/8" DP.
Wash down and tag DPOB at 7659' MD.
Drill out DPOB & ream clean. Drift to
ensure clean. Rack back 5-7/8" stand.
250 gpm; 1650 psi
40 rpm; Tq 4-7K
WOB 6K
PU 118K
SO 139K
ROT 126K
7,635.0 7,635.0
8/5/2023
05:00
8/5/2023
06:00
1.00 INTRM2, DRILLOUT PULD P Single in the hole from 7635'-8200' MD,
18 joints of 4-1/2" DP.
7,635.0 8,200.0
8/5/2023
06:00
8/5/2023
06:45
0.75 INTRM2, DRILLOUT TRIP P Trip in the hole from 8200'-9148' MD,
SO 111K.
8,200.0 9,148.0
8/5/2023
06:45
8/5/2023
07:30
0.75 INTRM2, DRILLOUT CIRC P Fill pipe, test MWD, & turn on
SonicScope @ 264 gpm, 1895 psi.
9,148.0 9,148.0
8/5/2023
07:30
8/5/2023
11:15
3.75 INTRM2, DRILLOUT TRIP P Trip in the hole from 9148'-12,412' MD,
logging cement at 1800 fph. Lost slack
off weight at 12,412' MD. PU172K, SO
74K.
9,148.0 12,412.0
8/5/2023
11:15
8/5/2023
11:30
0.25 INTRM2, DRILLOUT TRIP P Trip out of the hole racking back 1 stand
of 4-1/2" DP from 12,412'-12,349' MD.
12,412.0 12,349.0
8/5/2023
11:30
8/5/2023
12:15
0.75 INTRM2, DRILLOUT WASH P Make up D425 P X B VX57, change out
elevators, & wash down a stand of 5-
7/8" DP from 12,349'-12,442' MD.
232 gpm; 1752 psi
50 rpm; Tq 5-9K
ROT 135K
12,349.0 12,442.0
8/5/2023
12:15
8/5/2023
12:30
0.25 INTRM2, DRILLOUT SEQP P Upload well file & configuration to
NOVOS to test reaming settings and
functions.
12,442.0 12,442.0
8/5/2023
12:30
8/5/2023
13:15
0.75 INTRM2, DRILLOUT WASH P Wash down from 12,442'-12,511' MD.
242 gpm; 1988 psi
60 rpm; Tq 7-12K
PU 173K
SO 74K
ROT 134K
12,442.0 12,511.0
8/5/2023
13:15
8/5/2023
13:30
0.25 INTRM2, DRILLOUT SEQP P Attempt to test NOVOS settings &
functions, observed multiple top drive
faults. Test canceled.
12,511.0 12,511.0
8/5/2023
13:30
8/5/2023
14:15
0.75 INTRM2, DRILLOUT DRLG P Wash down, tag & drill plugs/landing
collar from 12,511'-12,529' MD, tag
plugs at 12,528' MD.
242 gpm; 1863 psi
70 rpm; Tq 10-15K
WOB 5-8K
PU 173K
SO 74K
ROT134K
12,511.0 12,529.0
8/5/2023
14:15
8/5/2023
16:45
2.50 INTRM2, DRILLOUT DRLG P Drill out cement from 12,529'-12,542'
MD.
180-200 gpm; 900-1865 psi
70-100 rpm; Tq 10-15K
WOB 5-18K
PU 173K
SO 74K
ROT 134K
12,529.0 12,542.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 29/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/5/2023
16:45
8/5/2023
18:45
2.00 INTRM2, DRILLOUT CIRC P Circulate till shakers cleaned up,
reciprocating full stand.
262 gpm; 2010 psi
70 rpm; Tq 11K
PU 173K
SO 74K
ROT 134K
12,542.0 12,542.0
8/5/2023
18:45
8/5/2023
19:15
0.50 INTRM2, DRILLOUT MPDA P Install 5-7/8" bearing in RCD as per
MPD Advisor.
12,542.0 12,542.0
8/5/2023
19:15
8/5/2023
20:30
1.25 INTRM2, DRILLOUT MPDA P Line up and flood MPD lines. Calibrate
MPD chokes & set up parameters per
MPD Advisor.
12,542.0 12,542.0
8/5/2023
20:30
8/5/2023
21:15
0.75 INTRM2, DRILLOUT SEQP P Install & perform NOVOS & MPD ramp
tests, good tests. Perform off bottom
reaming with NOVOS & MPD, good
tests.
12,542.0 12,542.0
8/5/2023
21:15
8/6/2023
00:00
2.75 INTRM2, DRILLOUT DISP P Displace from 9.2 ppg FWP to 8.1 ppg
Versaclean OBM system. Prep pits &
verify line ups. Pump 100 bbls of
Deepclean spacer, chased with 518 bbls
of 8.1 ppg Versaclean OBM at 24:00
hrs.
260 gpm; 2350 psi
60 rpm; Tq 8K
PU 134K
SO 126K
ROT 144K
12,542.0 12,542.0
8/6/2023
00:00
8/6/2023
01:00
1.00 INTRM2, DRILLOUT DISP P Continue displacement from 9.2 ppg
FWP to 8.1 ppg Versaclean OBM
system. Observed Deepclean spacer
back at 706 bbls pumped. Dumped 30
bbls of interface. Shut down with 839
bbls pumped & good OBM at surface.
Flush remaining pumps with OBM.
260 gpm; 2242 psi
60 rpm; Tq 7K
PU 135K
SO 127K
ROT 144K
12,542.0 12,542.0
8/6/2023
01:00
8/6/2023
01:15
0.25 INTRM2, DRILLOUT CIRC P Obtain torque / drag & slow circulating
rates.
30 rpm; Tq 7K
PU 182K
SO 100K
ROT 143K
12,542.0 12,542.0
8/6/2023
01:15
8/6/2023
02:15
1.00 INTRM2, DRILLOUT CLEN P Clean pits, transfer lines, & shaker from
displacement. SIMOPS change out top
drive grabber dies.
12,542.0 12,542.0
8/6/2023
02:15
8/6/2023
05:15
3.00 INTRM2, DRILLOUT RGRP T Loss of hi-line power, rig blacked out.
Troubleshoot & get rig generators on
line. Troubleshoot Amphion system
alarms.
12,542.0 12,542.0
8/6/2023
05:15
8/6/2023
06:00
0.75 INTRM2, DRILLOUT CLEN P Finish cleaning up from displacement.
SIMOPS change out top drive grabber
dies.
12,542.0 12,542.0
8/6/2023
06:00
8/6/2023
08:00
2.00 INTRM2, DRILLOUT CIRC T MPD communication failure with PLC.
NOV remote link in and reset comms.
Test MPD calibration and functions. Test
MWD tools.
12,542.0 12,542.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 30/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/6/2023
08:00
8/6/2023
10:30
2.50 INTRM2, DRILLOUT DRLG P Drill cement from 12,542'-12,695' MD,
tagging float collar.
250 gpm; 2242 psi
60 rpm; Tq 9-11K
WOB 5-8K
ECD 10.1
PU 180K
SO 102K
ROT 140K
12,542.0 12,695.0
8/6/2023
10:30
8/6/2023
13:00
2.50 INTRM2, DRILLOUT DRLG P Drill float collar & cement from 12,695'-
12,719' MD.
180-260 gpm; 1084-2270 psi
40-100 rpm; Tq 8-12K
WOB 5-15K
ECD 10.1
PU 180K
SO 102K
ROT 140K
12,695.0 12,719.0
8/6/2023
13:00
8/6/2023
13:30
0.50 INTRM2, DRILLOUT MPDA P Clear debris from MPD choke. Test
MPD systems. Rig on hi-line 13:09 hrs.
12,719.0 12,719.0
8/6/2023
13:30
8/6/2023
18:00
4.50 INTRM2, DRILLOUT DRLG P Drill cement in casing, shoe & cement in
rat hole from 12,719'-12,825' MD. Tag
shoe at 12,821' MD.
180-250 gpm; 1358-2233 psi
60-100 rpm; Tq 8-12K
WOB 5-12K
ECD 10.25
PU 180K
SO 102K
ROT 140K
12,719.0 12,825.0
8/6/2023
18:00
8/6/2023
18:30
0.50 INTRM2, DRILLOUT DDRL P Drill 6-1/2" production section from
12,825'-12,845' MD.
260 gpm; 2340 psi
100 rpm; Tq on 10K; off 9K
WOB 2-4K
ECD 10.21
PU 180K
SO 102K
ROT 140K
ADT .37; BIT .37
12,825.0 12,845.0
8/6/2023
18:30
8/6/2023
21:15
2.75 INTRM2, DRILLOUT CIRC P Circulate hole clean. Pump sweep, pull
into shoe and rack a stand back from
12,845'-12,812' MD.
275 gpm; 2340 psi
60 rpm; Tq 10K
ECD 10.21
PU 142K
SO 123K
ROT 144K
12,845.0 12,812.0
8/6/2023
21:15
8/6/2023
22:00
0.75 INTRM2, DRILLOUT RURD P Rig up to perform FIT. Rig up cement
line, head pin & 1502 equipment.
Equalize pressures on drill pipe and kill
line with trapped 660 psi below the
upper pipe rams.
12,812.0 12,812.0
8/6/2023
22:00
8/6/2023
22:30
0.50 INTRM2, DRILLOUT FIT P Perform FIT to 14.5 ppg EMW, with 8.2
ppg OBM at 7-5/8" casing shoe 4057'
TVD, charted. Pressure up from MPD
shut in of 660 psi to 1329 psi with 2.6
bbls pumped. Shut in pressure observed
for 10 minutes with a final pressure of
1032 psi. Bled back 1 bbl.
12,812.0 12,812.0
8/6/2023
22:30
8/6/2023
23:15
0.75 PROD1, DRILL RURD P Equalize pressures with MPD system.
Open upper pipe rams & establish
circulation, verifying MPD choke
functioning correctly. Rig down test
equipment & blow down lines.
12,812.0 12,812.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 31/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/6/2023
23:15
8/7/2023
00:00
0.75 PROD1, DRILL WASH P Make up a stand of 5-7/8" DP. Pump up
FIT data from MWD. Wash & ream from
12,812'-12,845' MD.
260 gpm; 2665 psi
60 rpm; Tq 10K
SO ROT 114K
12,812.0 12,845.0
8/7/2023
00:00
8/7/2023
07:00
7.00 PROD1, DRILL DDRL P Drill 6-1/2" production section from
12,845'-13,273' MD, 4117' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2877 psi
100-120 rpm; Tq on 12K; off 10K
WOB 6-8K
ECD 11.25
PW 185K
SW NA
RW 140K
Total Gas 212
ADT 5.79; BIT 6.16
12,845.0 13,273.0
8/7/2023
07:00
8/7/2023
11:15
4.25 PROD1, DRILL MPDA T Troubleshoot MPD communication
issues with NOV remote operations.
Circulate & reciprocate pipe.
280 gpm; 2560 psi
80 rpm; Tq 10K
RPW 146K
RSW 136K
13,273.0 13,183.0
8/7/2023
11:15
8/7/2023
12:00
0.75 PROD1, DRILL SMPD T Strip out of the hole from 13,183'-12783'
MD for MPD equipment issues.
PW 180-190K
MPD BP in slips 435 psi; out 535 psi
13,183.0 12,783.0
8/7/2023
12:00
8/7/2023
14:15
2.25 PROD1, DRILL MPDA T Troubleshoot and identify with NOV
remote operations main Servo Motor
Drive Control for choke A in PLC needed
replaced. Replaced drive, NOV upload
data & configure. Tested drive &
functions of choke A. During repairs
Orbit valve was closed, maintaining 400-
450 psi on well.
12,783.0 12,783.0
8/7/2023
14:15
8/7/2023
16:00
1.75 PROD1, DRILL SMPD T Unable to strip in the hole due to loss of
slack off weight. Wash & ream in the
hole from 12,783'-13,273' MD,
maintaining 10.3 ppg EMW at the shoe.
95 gpm; 790 psi
20 rpm; Tq 6-7K
RSW 110-120K
12,783.0 13,273.0
8/7/2023
16:00
8/7/2023
18:00
2.00 PROD1, DRILL DDRL P Drill 6-1/2" production section from
13,273'-13,367' MD, 4144' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2880 psi
100-120 rpm; Tq on 11-14K; off 10-12K
WOB 6-9K
ECD 11.24
PW 185K
SW NA
RW 140K
Total Gas 20
ADT 1.36; BIT 7.52
13,273.0 13,367.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 32/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/7/2023
18:00
8/8/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production section from
13,367'-13,740' MD, 4198' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2907 psi
120 rpm; Tq on 12K; off 10-12K
WOB 6K
ECD 11.37
PW 201K
SW NA
RW 141K
Total Gas 87
ADT 4.76; BIT 12.28
13,367.0 13,740.0
8/8/2023
00:00
8/8/2023
00:30
0.50 PROD1, DRILL SRVY P Shoot survey for Directional Driller.
Obtain slow circulating rates.
13,740.0 13,740.0
8/8/2023
00:30
8/8/2023
02:00
1.50 PROD1, DRILL BKRM P Back ream out of the hole circulating 1
bottoms up from 13,740'-13,645' MD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2860 psi
100 rpm; Tq 12K
ECD 11.29
13,740.0 13,645.0
8/8/2023
02:00
8/8/2023
04:15
2.25 PROD1, DRILL SMPD P Strip out of the hole from 13,650'-
12,450' MD, Maintaining 11.0 ppg EMW,
with anchor point at 4263' TVD, PW
182K.
13,645.0 12,450.0
8/8/2023
04:15
8/8/2023
07:30
3.25 PROD1, DRILL MPDA P Change out RCD bearings from 5-7/8"
to 4-1/2". Close annular & maintain 500
- 600 psi on wellbore. Rack back stand
with 5-7/8" bearing on bottom. PW 178K
stripping through annular. Make up 5-
7/8" X 4-1/2" XO to the saver sub on the
top drive. Lay down a single off of an
stand of 4-1/2" drill pipe. Install 4-1/2"
RCD bearing on the double of drill pipe.
Strip through annular & engage clamp
on bearing. SW 76-80K, PW 180K.
12,450.0 12,450.0
8/8/2023
07:30
8/8/2023
08:30
1.00 PROD1, DRILL MPDA P Calibrate MPD chokes. Pressure up
MPD system to match trapped pressure
below the annular. Open annular, close
kill line & bleed off kill line pressure. Pick
up 4-1/2" DP single and make up to
string.
12,450.0 12,441.0
8/8/2023
08:30
8/8/2023
09:30
1.00 PROD1, DRILL WASH P Wash and ream down from 12,441'-
12,629' MD.
100 gpm; 960 psi
20 rpm; Tq 5K
RSW 104K
RW 135K
12,441.0 12,629.0
8/8/2023
09:30
8/8/2023
10:00
0.50 PROD1, DRILL RURD T While making up a stand of 4-1/2" DP
rig tongs slipped. Crossover was over
torque to 80K. Change out XO.
12,629.0 12,629.0
8/8/2023
10:00
8/8/2023
11:00
1.00 PROD1, DRILL SVRG P Change out dies on rig tongs. SIMOPS
lay down top single from stand 131 &
pick up single from the pipe shed.
12,629.0 12,629.0
8/8/2023
11:00
8/8/2023
12:00
1.00 PROD1, DRILL WASH P Wash and ream down from 12,629'-
12,818' MD.
100 gpm; 982 psi
30 rpm; Tq 4-6K
RSW 106-112K
RW 136K
12,629.0 12,818.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 33/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/8/2023
12:00
8/8/2023
21:00
9.00 PROD1, DRILL MPDA T Troubleshoot choke A fault issue. NOV
remote support diagnosis faulty memory
card in choke A drive. Replace memory
card. Restart system. Run various tests.
Re-home & operate / test both chokes,
no faults. Maintain 500-550 psi on
annulus with Orbit valve closed, using
kill line to maintain pressure. SIMOPS
remove 5-7/8" bearing from drill pipe
stand. Change element on bearing.
Install bearing back on stand of 5-7/8"
drill pipe & rack back in the derrick.
12,818.0 12,818.0
8/8/2023
21:00
8/8/2023
23:45
2.75 PROD1, DRILL WASH P Wash and ream down from 12,818'-
13,481' MD.
100 gpm; 1020 psi
20 rpm; Tq 6K
RSW 106-114K
RW 133K
12,818.0 13,481.0
8/8/2023
23:45
8/9/2023
00:00
0.25 PROD1, DRILL CIRC P Begin circulating bottoms up
reciprocating from 13,481'-13,500' MD.
280 gpm; 2919 psi
100 rpm; Tq 11K
ECD 11.22
RSW 120K
RW 134K
13,481.0 13,500.0
8/9/2023
00:00
8/9/2023
01:30
1.50 PROD1, DRILL CIRC P Finished circulating bottoms up
reciprocating from 13,500'-13,574' MD.
280 gpm; 2920 psi
100 rpm; Tq 11K
ECD 11.43
RPW 136K
RSW 120K
RW 134K
13,500.0 13,574.0
8/9/2023
01:30
8/9/2023
03:45
2.25 PROD1, DRILL MPDA P Changed out RCD bearings from 4-1/2"
to 5-7/8". Closed annular & maintain
500 - 550 psi on wellbore. Stripped
through annular pulling 4-1/2" bearing to
the rig floor. Broke out single & removed
bearing. Stripped in the hole with 4-1/2"
single. PW 188K; SW 60-80K stripping
through annular. Made up stand of 5-
7/8" with bearing installed on stand.
Stripped through annular & engaged
clamp on bearing. Stripping through
annular SW 80K,
13,574.0 13,574.0
8/9/2023
03:45
8/9/2023
04:30
0.75 PROD1, DRILL REAM P Reamed from 13,574'-13,740' MD,
maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2937 psi
100 rpm; Tq 12-14K
RSW 118K
13,574.0 13,740.0
8/9/2023
04:30
8/9/2023
06:00
1.50 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
13,740'-13,856' MD, 4212' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2914 psi
120 rpm; Tq on 13K; off 10K
WOB 7K
ECD 11.20
PW 188K
SW NA
RW 138K
Total Gas 13
ADT 1.24; BIT 13.52
13,740.0 13,856.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 34/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/9/2023
06:00
8/9/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
13,856'-14,208' MD, 4218' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2900 psi
120 rpm; Tq on 10-14K; off 11-13K
WOB 5-10K
ECD 11.22
PW 198K
SW NA
RW 135K
Total Gas 124
ADT 3.85; BIT 17.37
13,856.0 14,208.0
8/9/2023
12:00
8/9/2023
18:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
14,208'-14,593' MD, 4221' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2880 psi
120 rpm; Tq on 10-14K; off 11-13K
WOB 5-10K
ECD 11.18
PW 196K
SW NA
RW 134K
Total Gas 124
ADT 4.43; BIT 21.80
14,208.0 14,593.0
8/9/2023
18:00
8/10/2023
00:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
14,593'-15,040' MD, 4221' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4263' TVD.
280 gpm; 2945 psi
120 rpm; Tq on 15K; off 12K
WOB 4-9K
ECD 11.44
PW 212K
SW NA
RW 143K
Total Gas 137
ADT 4.41; BIT 26.21
14,593.0 15,040.0
8/10/2023
00:00
8/10/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
15,040'-15,521' MD, 4257' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm;3000 psi
120 rpm; Tq on 16K; off 15K
WOB 6-10K
ECD 11.60
PW 212K
SW NA
RW 143K
Total Gas 92
ADT 4.33; BIT 30.54
15,040.0 15,521.0
8/10/2023
06:00
8/10/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
15,521'-15,986' MD, 4270' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm;2900 psi
120 rpm; Tq on 18K; off 14K
WOB 5-10K
ECD 11.35
PW 223K
SW NA
RW 150K
Total Gas 150
ADT 4.19; BIT 34.73
15,521.0 15,986.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 35/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/10/2023
12:00
8/10/2023
18:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
15,986'-16,444' MD, 4283' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm;2880 psi
100-120 rpm; Tq on 17K; off 14K
WOB 5-10K
ECD 11.08
PW 248K
SW NA
RW 150K
Total Gas 98
ADT 4.08; BIT 38.81
15,986.0 16,444.0
8/10/2023
18:00
8/11/2023
00:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
16,444'-16,913' MD, 4303' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 2863 psi
100-110 rpm; Tq on 18K; off 15K
WOB 6-10K
ECD 11.14
PW 252K
SW NA
RW 157K
Total Gas 126
ADT 4.06; BIT 42.87
16,444.0 16,913.0
8/11/2023
00:00
8/11/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
16,913'-17,382' MD, 4332' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 2883 psi
110 rpm; Tq on 20K; off 14K
WOB 4-7K
ECD 11.17
PW 260K
SW NA
RW 159K
Total Gas 165
ADT 3.95; BIT 46.82
16,913.0 17,382.0
8/11/2023
06:00
8/11/2023
12:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
17,382'-17,889' MD, 4349' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 2907 psi
110 rpm; Tq on 21K; off 14K
WOB 4-7K
ECD 11.31
PW 261K
SW NA
RW 160K
Total Gas 169
ADT 4.48; BIT 51.30
17,382.0 17,889.0
8/11/2023
12:00
8/11/2023
18:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
17,889'-18,394' MD, 4367' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 2896 psi
100 rpm; Tq on 19K; off 14K
WOB 5-10K
ECD 11.33
PW 260K
SW NA
RW 160K
Total Gas 159
ADT 4.62; BIT 55.92
17,889.0 18,394.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 36/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/11/2023
18:00
8/12/2023
00:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
18,394'-18,861' MD, 4377' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 2947 psi
100-110 rpm; Tq on 18K; off 13K
WOB 6-9K
ECD 11.27
PW 261K
SW NA
RW 158K
Total Gas 149
ADT 4.04; BIT 59.96
18,394.0 18,861.0
8/12/2023
00:00
8/12/2023
06:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
18,861'-19,324' MD, 4369' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD. Obtain slow
circulating rates.
280 gpm; 3045 psi
110 rpm; Tq on 19K; off 14K
WOB 3-9K
ECD 11.63
PW 263K
SW NA
RW 157K
Total Gas 124
ADT 4.23; BIT 64.19
18,861.0 19,324.0
8/12/2023
06:00
8/12/2023
11:00
5.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19,324'-19,695' MD, 4354' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 3100 psi
110 rpm; Tq on 20K; off 20K
WOB 3-10K
ECD 11.94
PW 260K
SW NA
RW 158K
Total Gas 124
ADT 3.48; BIT 67.67
19,324.0 19,695.0
8/12/2023
11:00
8/12/2023
12:45
1.75 PROD1, DRILL RURD T When making up the stand prior to
drilling down, rig tongs slipped twice.
Unable to break out of stand #207 with
the saver sub. Inspected grabber dies &
steamed drill pipe box end. Reattempted
to break out using top drive grabber,
with no success. Attempted to break out
with rig tongs, with no success. Broke
out saver sub from lower IBOP on top
drive, leaving saver sub made up to the
stump.
19,695.0 19,695.0
8/12/2023
12:45
8/12/2023
13:15
0.50 PROD1, DRILL SVRG P Serviced rig. SIMOPS attempted to
break out saver sub from drill pipe with
ST-120. Unable to break out with 120K
torque.
19,695.0 19,695.0
8/12/2023
13:15
8/12/2023
14:15
1.00 PROD1, DRILL RURD T Laid down top single with saver sub
made up on it. Made up new saver sub
onto top drive. Picked up replacement
single of drill pipe and washed down to
bottom.
280 gpm; 3066 psi
100 gpm; Tq 17K
RSW 134K
19,695.0 19,695.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 37/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/12/2023
14:15
8/12/2023
18:00
3.75 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19,695'-19,973' MD, 4341' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD. Obtain slow
circulating rates.
280 gpm; 3125 psi
110 rpm; Tq on 21K; off 20K
WOB 9K
ECD 12.01
PW 268K
SW NA
RW 160K
Total Gas 82
ADT 2.43; BIT 70.10
19,695.0 19,973.0
8/12/2023
18:00
8/13/2023
00:00
6.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
19,973'-20,437' MD, 4353' TVD.
Maintaining 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 3147 psi
110 rpm; Tq on 22K; off 16K
WOB 7K
ECD 12.19
PW 269K
SW NA
RW 159K
Total Gas 93
ADT 4.50; BIT 74.60
19,973.0 20,437.0
8/13/2023
00:00
8/13/2023
04:00
4.00 PROD1, DRILL DDRL P Drilled 6-1/2" production section from
20,437'-20,736' MD, 4364' TVD.
Maintained 11.0 ppg EMW, with anchor
point at 4293' TVD.
280 gpm; 3138 psi
110 rpm; Tq on 23K; off 14K
WOB 10K
ECD 12.14
PW 277K
SW NA
RW 159K
Total Gas 98
ADT 2.97; BIT 77.57
20,437.0 20,736.0
8/13/2023
04:00
8/13/2023
04:45
0.75 PROD1, TRIPCAS SRVY P Obtained final torque / drag, slow
circulating rates, & final survey.
30 rpm; Tq 15K
PW 277K
SW N/A
RW 159K
20,736.0 20,736.0
8/13/2023
04:45
8/13/2023
05:30
0.75 PROD1, TRIPCAS RURD P Spaced out drill string across BOP
stack. Lined up MPD for draw down test.
Attempted to test, observed choke B
leaking. Lined up to choke manifold to
closed super choke. Flooded lines back
to pit 5.
20,736.0 20,736.0
8/13/2023
05:30
8/13/2023
06:45
1.25 PROD1, TRIPCAS OTHR P Performed static drawdown lined up to
the rig choke, MPD bearing with Orbit
valve closed, rotating at 10 rpm. Initial
shut in pressure was 550 psi. Pressure
was reduced in 40 psi increments &
monitored for 5 minutes each time. Final
shut in pressure was 295 psi; 9.6 ppg
EMW. Wellbore had 8.2 ppg OBM &
intermediate 2 shoe at 4057' TVD.
20,736.0 20,736.0
8/13/2023
06:45
8/13/2023
09:00
2.25 PROD1, TRIPCAS CIRC P Circulated bottoms up reciprocating.
280 gpm; 3171 psi
110 rpm; Tq 18-21K
RW 130K
20,736.0 20,736.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 38/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/13/2023
09:00
8/13/2023
09:45
0.75 PROD1, TRIPCAS FIT P Performed open hole FIT to 13.0 ppg
EMW, with 8.2 ppg OBM, at TD 20,736'
MD, 4364' TVD. Pressured up to 1086
psi with 3.6 bbls and shut in. Monitored
pressure for 10 minutes with a final
pressure of 622 psi.
20,736.0 20,736.0
8/13/2023
09:45
8/13/2023
12:00
2.25 PROD1, TRIPCAS BKRM P Backreamed out of the hole from
20,736'-20,345' MD. Maintained 11.0
ppg EMW, with anchor point at 4293'
TVD.
280 gpm; 3010 psi
110 rpm; Tq 15-20K
ECD 11.59
RPW 155-160K
20,736.0 20,345.0
8/13/2023
12:00
8/13/2023
18:00
6.00 PROD1, TRIPCAS BKRM P Backreamed out of the hole from
20,345'-17,845' MD. Maintained 11.0
ppg EMW, with anchor point at 4293'
TVD.
280 gpm; 3000 psi
110 rpm; Tq 13-15K
ECD 11.5
RPW 155-160K
20,345.0 17,845.0
8/13/2023
18:00
8/13/2023
21:45
3.75 PROD1, TRIPCAS BKRM P Backreamed out of the hole from
17,845'-16,515' MD. Maintained 11.0
ppg EMW, with anchor point at 4293'
TVD. Observed pressure increased to
3293 psi & ECD spiked to 13.16.
280 gpm; 2870 psi
110 rpm; Tq 14K
ECD 11.1
RPW 150-155K
17,845.0 16,515.0
8/13/2023
21:45
8/14/2023
00:00
2.25 PROD1, TRIPCAS REAM T Observed pressure increase and
reduced pump rate & staged in the hole
from 16,515'-16,651' MD to establish
circulation with varying parameters.
Observed initial loss of 48 bbls, with
partial losses of 30 bbls after. Pumped
50 bbls 35 ppb LCM pill.
75-120 gpm 780-1300 psi
30-110 rpm; Tq 7-25K
RSW 140-151K
RW 154K
16,515.0 16,651.0
8/14/2023
00:00
8/14/2023
06:00
6.00 PROD1, TRIPCAS REAM T Continued to stage in the hole to clear
flow restriction from 16,651'-16,820' MD.
Attempted to stage up pump rate &
rotary as hole dictated.
75-=130 gpm; 850-1300 psi
60-90 rpm; Tq 13-17K
RW 154K
16,651.0 16,820.0
8/14/2023
06:00
8/14/2023
12:00
6.00 PROD1, TRIPCAS CIRC T Reciprocated pipe to clear flow
restriction from 16,820'-16,725' MD.
Attempted to stage up pump rate &
rotary as hole dictated.
100-150 gpm; 750-1650 psi
100-150 rpm; Tq 18K
RW 146K
16,820.0 16,820.0
8/14/2023
12:00
8/14/2023
15:45
3.75 PROD1, TRIPCAS CIRC T Staged up flow rate & reciprocated
string from 16,820'-16,725' MD.
160-280 gpm; 1250-2745 psi
100 rpm; Tq 13K
RW 146K
16,820.0 16,820.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 39/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/14/2023
15:45
8/14/2023
17:00
1.25 PROD1, TRIPCAS CIRC T Circulated bottoms up from 16,820'-
16,725' MD, reciprocating. Maintained
10.5 ppg EMW, with anchor point at
4293' TVD.
260 gpm; 2730 psi
100 rpm; Tq 15K
RW 156K
16,820.0 16,725.0
8/14/2023
17:00
8/14/2023
18:00
1.00 PROD1, TRIPCAS BKRM T Backreamed out of the hole from
16,725'-16,542' MD. Maintained 10.5
ppg EMW, with anchor point at 4293'
TVD.
280 gpm; 2720 psi
100 rpm; Tq 15K
ECD 10.4
RW 156K
16,725.0 16,542.0
8/14/2023
18:00
8/14/2023
18:45
0.75 PROD1, TRIPCAS REAM T Observed pressure increase & torque
spike on connection. Reamed down
from 16,542'-16,634' MD with reduced
rates. Losses observed.
200 gpm; 1990 psi
100 rpm; 19K
RSW 139K
16,542.0 16,634.0
8/14/2023
18:45
8/15/2023
00:00
5.25 PROD1, TRIPCAS BKRM T Backreamed out of the hole from
16,634'-16,355' MD, with varying
parameters as hole conditions dictated.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Pumped 50 bbls, 35
ppb LCM pills as needed.
200-230 gpm; 1830-2320 psi
60-100 rpm; Tq 14-28K
RPW159K
RSW 131K
RW 156K
16,634.0 16,355.0
8/15/2023
00:00
8/15/2023
06:00
6.00 PROD1, TRIPCAS BKRM T Backreamed out of the hole from
16,355'-15,981' MD, with varied
parameters as hole conditions dictated.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Pumped 50 bbls, 35
ppb LCM pills as needed.
190-220 gpm; 1758-2157 psi
60-100 rpm; Tq 13-26K
RPW158K
RW 157K
16,355.0 15,981.0
8/15/2023
06:00
8/15/2023
12:00
6.00 PROD1, TRIPCAS BKRM T Backreamed out of the hole from
15,981'-15,577' MD, with varied
parameters as hole conditions dictated.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Pumped 50 bbls, 35
ppb LCM pills as needed.
170 gpm; 1748 psi
60 rpm; Tq 13-27K
RPW156K
RW 149K
15,981.0 15,577.0
8/15/2023
12:00
8/15/2023
18:00
6.00 PROD1, TRIPCAS BKRM T Backreamed out of the hole from
15,577'-15,050' MD, with varied
parameters as hole conditions dictated.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Pumped 50 bbls, 35
ppb LCM pills as needed.
170-255 gpm; 1510-2423 psi
60 rpm; Tq 14-27K
RPW158K
RW 151K
15,577.0 15,050.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 40/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/15/2023
18:00
8/16/2023
00:00
6.00 PROD1, TRIPCAS BKRM T Backreamed out of the hole from
15,050'-14,257' MD, with varied
parameters as hole conditions dictated.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Pumped 50 bbls, 35
ppb LCM pills as needed.
260 gpm; 2480 psi
60 rpm; Tq 11-15K
RW 147K
15,050.0 14,257.0
8/16/2023
00:00
8/16/2023
02:15
2.25 PROD1, TRIPCAS BKRM P Backreamed out of the hole from
14,257'-13,763' MD, with varied
parameters as hole conditions dictated.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Pumped 50 bbls, 35
ppb LCM pills as needed.
280 gpm; 2740 psi
80rpm; Tq 12-14K
ECD: 10.43
RW 143K
14,257.0 13,763.0
8/16/2023
02:15
8/16/2023
04:15
2.00 PROD1, TRIPCAS BKRM P Backreamed out of the hole from
13,763'-13,669' MD, while circulating
bottoms up on stand #143. Continue
BROOH from 13,669' - 13,559'.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Pumped 50 bbls, 35
ppb LCM pills as needed.
280 gpm; 2736 psi
100 rpm; Tq 11-14K
ECD: 10.48
RW 142K
13,763.0 13,559.0
8/16/2023
04:15
8/16/2023
05:30
1.25 PROD1, TRIPCAS MPDA P PJSM, Pull 5-7/8" MPD bearing under
pressure as per MPD rep. Space out,
close annular, bled off MPD pressure
and open clamp. Maintain 500-550 psi
on wellbore via kill line. Strip through
annular (reduced closing pressure to
~450 psi) until bearing at rig floor. Rack
back stand with bearing. Visual on
bearing condition is good. Stripping P/U
= 192K.
13,559.0 13,559.0
8/16/2023
05:30
8/16/2023
07:00
1.50 PROD1, TRIPCAS MPDA P Install 4-1/2" bearing under
pressure.Stab bearing with working 4-
1/2" single, m/u to string, strip in hole
thru annular. Close RCD clamp, push
and pull test verifying clamp is locked.
Maintain 500-550 psi on wellbore via kill
line.
Equalize pressure under bearing to
wellbore pressure at 560 psi. Verify
MPD choke is working, open annular.
L/D working single.
Stripping S/O = 75k.
13,559.0 13,599.0
8/16/2023
07:00
8/16/2023
12:00
5.00 PROD1, TRIPCAS BKRM P Backreamed out of the hole from
13,599'-13,057' MD, Maintained 10.5
ppg EMW, with anchor point at 4293'
TVD.
280 gpm; 2727 psi
100 rpm; Tq 11-14K
ECD: 10.78
RW 147K
13,599.0 13,057.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 41/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/16/2023
12:00
8/16/2023
13:30
1.50 PROD1, TRIPCAS BKRM P Backreamed out of the hole from
13,057'-12,817' MD, Maintained 10.5
ppg EMW, with anchor point at 4293'
TVD.
280 gpm; 2703 psi
100 rpm; Tq 10K
ECD: 10.57
RW 134K
13,057.0 12,817.0
8/16/2023
13:30
8/16/2023
14:15
0.75 PROD1, TRIPCAS CIRC P Open Well Commander as per SLB DD.
Drop 1.75" steel ball #1, pump down at
280 gpm for 750 stks, decreased to 85
gpm at 576 psi. Ball on seat at 994 stks,
shifted opened at 2669 psi, 1010 total
stks pumped, 280 gpm at 1024 psi.
12,817.0 12,817.0
8/16/2023
14:15
8/16/2023
16:45
2.50 PROD1, TRIPCAS CIRC P Circulate staging up rate ~3 bottoms
ups through open well commander while
rotating and reciprocating from 12,817'-
12,727'. No losses. Observed
increased load of fines over shakers
decreasing on each bottoms up.
600 gpm
2748 psi
60 rpm
9K Tq
12,817.0 12,727.0
8/16/2023
16:45
8/16/2023
18:00
1.25 PROD1, TRIPCAS CIRC P Closed Well Commander as per SLB
DD. Drop 1.75" steel ball #2, pump
down at 280 gpm at 992 psi for 778
stks, decreased to 85 gpm at 576 psi.
Ball on seat at 943 stks, shifted closed
at 2669 psi, 958 total stks pumped, 280
gpm at 2630 psi.
P/U = 178K
S/O = 83K
ROT = 128K
Tq =8K
12,727.0 12,817.0
8/16/2023
18:00
8/16/2023
18:45
0.75 PROD1, TRIPCAS TRIP P Pipe management, move 8 stands 4-
1/2" drill pipe to ODS derrick. Note: Not
required to TIH to 19,700'.
12,817.0 12,817.0
8/16/2023
18:45
8/16/2023
19:45
1.00 PROD1, TRIPCAS MPDA P PJSM, Pull 4-1/2" MPD bearing under
pressure as per MPD rep. Space out,
close annular, bled off MPD pressure
and open clamp. Maintain 500-550 psi
on wellbore via kill line. Strip through
annular (reduced closing pressure to
~450 psi) until bearing at rig floor. Strip
bearing off stand and rack back stand.
Visual on bearing condition is good.
Stripping P/U = 175K.
12,817.0 12,817.0
8/16/2023
19:45
8/16/2023
20:45
1.00 PROD1, TRIPCAS MPDA P Install 5-7/8" bearing under pressure.
M/U stand with bearing already stripped
on, strip in hole thru annular. Close RCD
clamp, push and pull test verifying
clamp is locked. Maintain 500-550 psi
on wellbore via kill line.
Equalize pressure under bearing to
wellbore pressure at 540 psi. Verify
MPD choke is working, open annular.
Stripping S/O = 85-90k.
12,817.0 12,823.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 42/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/16/2023
20:45
8/17/2023
00:00
3.25 PROD1, TRIPCAS REAM P Stripping in the hole with low energy
reaming from 12,823' - 13,890'.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Monitor
displacement with isolated pit #5.
GPM = 100
PSI = 840
RPM = 30
TQ = 7-9K
P/U = 169K
S/O = 114K
ROT = 130K
12,823.0 13,890.0
8/17/2023
00:00
8/17/2023
06:00
6.00 PROD1, TRIPCAS REAM P Stripping in the hole with low energy
reaming from 13,890' - 16,622'.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Monitor
displacement with isolated pit #5.
GPM = 75-100
PSI = 700-840
RPM = 30
TQ = 7-10K
ROT S/O = 132K
ROT = 144K
13,890.0 16,622.0
8/17/2023
06:00
8/17/2023
12:00
6.00 PROD1, TRIPCAS REAM P Stripping in the hole with low energy
reaming from 16,622' - 19,236'.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Monitor
displacement with isolated pit #5.
GPM = 75
PSI = 779
RPM = 30
TQ = 7K
ROT = 146K
16,622.0 19,236.0
8/17/2023
12:00
8/17/2023
13:30
1.50 PROD1, TRIPCAS REAM P Stripping in the hole with low energy
reaming from 19,236' - 19,760'.
Maintained 10.5 ppg EMW, with anchor
point at 4293' TVD. Monitor
displacement with isolated pit #5.
GPM = 75
PSI = 813
RPM = 30
TQ = 9K
ROT = 146K
19,236.0 19,760.0
8/17/2023
13:30
8/17/2023
19:00
5.50 PROD1, TRIPCAS CIRC P Circulated 2 bottoms up from 19,760'-
19,680' MD, reciprocating. Maintained
10.5 ppg EMW, with anchor point at
4293' TVD.
GPM = 280
PSI = 3012
RPM = 100
TQ = 16K
ECD= 11.34
RW = 146K
19,760.0 19,680.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 43/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/17/2023
19:00
8/18/2023
00:00
5.00 PROD1, TRIPCAS DISP P PJSM. Displace well from 8.2 ppg to
10.1 ppg KWM as per Mud Engineer pit
plan following Beyond rollover schedule
while rotating and reciprocating from
19,760' to 19,680'. No losses.
GPM = 280-130
PSI = 3012-1210
RPM = 90
TQ = 15K
ECD= 11.27
RW = 146K
19,680.0 19,760.0
8/18/2023
00:00
8/18/2023
00:15
0.25 PROD1, TRIPCAS CIRC P P/U to 19,686', rack back stand 5-7/8"
DP. Flush mud pumps with 10.1 ppg
KWM.
19,760.0 19,686.0
8/18/2023
00:15
8/18/2023
00:45
0.50 PROD1, TRIPCAS OWFF P Static flow check to cellar. Well static. 19,686.0 19,686.0
8/18/2023
00:45
8/18/2023
01:15
0.50 PROD1, TRIPCAS CIRC P Obtain SPR's, line up through MPD to
maintain back pressure.
SPR's @ 19,682' MD 4,355' TVD w/
10.1 ppg @ 00:50 hrs.
#1 MP @ 10 spm = 495 psi, 20 spm =
880 psi
#2 MP @ 10 spm = 480 psi, 20 spm =
850 psi
19,686.0 19,682.0
8/18/2023
01:15
8/18/2023
06:00
4.75 PROD1, TRIPCAS SMPD P SOOH on elevators from 19,686' to
16,255'. Maintain back pressure with
MPD to mitigate swab/surge. Monitor
displacement on isolated Pit #4.
Dropped 2.5" hollow drift with tail wire
on stand # 204.
P/U = 215K
19,682.0 16,255.0
8/18/2023
06:00
8/18/2023
10:30
4.50 PROD1, TRIPCAS SMPD P SOOH on elevators from 16,255' to
12,760'. Maintain back pressure with
MPD to mitigate swab/surge. Monitor
displacement on isolated Pit #4.
P/U = 168K
16,255.0 12,760.0
8/18/2023
10:30
8/18/2023
11:00
0.50 PROD1, TRIPCAS OWFF P PJSM. Static flow check. Well static. 12,760.0 12,760.0
8/18/2023
11:00
8/18/2023
11:30
0.50 PROD1, TRIPCAS MPDA P Remove 5-7/8" RCD bearing as per
MPD rep.
12,760.0 12,760.0
8/18/2023
11:30
8/18/2023
12:00
0.50 PROD1, TRIPCAS MPDA P Install 4-1/2" RCD bearing as per MPD
rep.
12,760.0 12,760.0
8/18/2023
12:00
8/18/2023
13:00
1.00 PROD1, TRIPCAS SVRG P Conduct Novos torque release test as
per NOV rep and DDI RPC.
12,760.0 12,760.0
8/18/2023
13:00
8/18/2023
18:00
5.00 PROD1, TRIPCAS SMPD P SOOH on elevators from 12,760' to
7,353'. Maintain back pressure with
MPD to mitigate swab/surge. Monitor
displacement on isolated Pit #4.
P/U = 138K
12,760.0 7,353.0
8/18/2023
18:00
8/18/2023
23:15
5.25 PROD1, TRIPCAS SMPD P SOOH on elevators from 7,353' to 700'.
Maintain back pressure with MPD to
mitigate swab/surge. Monitor
displacement on isolated Pit #4.
P/U = 90K
7,353.0 700.0
8/18/2023
23:15
8/18/2023
23:30
0.25 PROD1, TRIPCAS OWFF P PJSM. Bled down MPD pressure. Static
flow check. Well static.
700.0 700.0
8/18/2023
23:30
8/19/2023
00:00
0.50 PROD1, TRIPCAS MPDA P Remove 4-1/2" RCD bearing as per
MPD rep.
700.0 700.0
8/19/2023
00:00
8/19/2023
00:15
0.25 PROD1, TRIPCAS MPDA P Finish removing 4-1/2" RCD bearing as
per MPD rep.
700.0 700.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 44/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/19/2023
00:15
8/19/2023
01:00
0.75 PROD1, TRIPCAS TRIP P POOH f/700' to BHA. Put 1 stand in
mousehole.
SIMOPS: Cleaning mud pits in
preperation for brine.
700.0 215.0
8/19/2023
01:00
8/19/2023
02:15
1.25 PROD1, TRIPCAS BHAH P PJSM. CLear floor, remove SLB RA
source as per MWD eng.
215.0 215.0
8/19/2023
02:15
8/19/2023
06:00
3.75 PROD1, TRIPCAS BHAH P L/D stand from mousehole and continue
POOH L/D BHA as per SLB DD.
215.0 0.0
8/19/2023
06:00
8/19/2023
08:30
2.50 COMPZN, CASING RURD P Clean and clear rig floor. Mobilize to rig
floor and r/u casing equipment for liner
run.
0.0 0.0
8/19/2023
08:30
8/19/2023
09:00
0.50 COMPZN, CASING PUTB P PJSM. M/U Citadel shoe track as per
detail.
0.0 0.0
8/19/2023
09:00
8/19/2023
12:00
3.00 COMPZN, CASING PUTB P RIH to 980' w/ 4.5" 12.6# / P110 / HYD
563 lower completion as per tally.
Torque 5,600 ft/lbs, install Hydroform
4.5" x 5.625" centralizers on every joint,
monitor displacement on pit #1.
P/U = 86K
S/O = 83K
0.0 980.0
8/19/2023
12:00
8/19/2023
18:00
6.00 COMPZN, CASING PUTB P RIH f/ 980' to 6,040' w/ 4.5" 12.6# /
P110 / HYD 563 lower completion as
per tally. Torque 5,600 ft/lbs, install
Hydroform 4.5" x 5.625" centralizers on
every joint, monitor displacement on pit
#1.
P/U = 92K
S/O = 89K
980.0 6,040.0
8/19/2023
18:00
8/19/2023
20:30
2.50 COMPZN, CASING PUTB P RIH f/ 6,040' to 7,309' w/ 4.5" 12.6# /
P110 / HYD 563 lower completion as
per tally. Torque 5,600 ft/lbs, install
Hydroform 4.5" x 5.625" centralizers on
every joint. M/U Baker SLZXP liner
hanger assy as per Baker rep. Monitor
displacement on pit #1.
P/U = 92K
S/O = 89K
6,040.0 7,309.0
8/19/2023
20:30
8/20/2023
00:00
3.50 COMPZN, CASING RUNL P RIH f/7,309' to 12,589' w/4.5" 12.6# /
P110 / HYD563 lower completion on 56
stands 4.5" DP. Fill with 10.1 ppg mud
on the fly and top off every 20 stands.
Monitor displacement on pit #5.
7,309.0 12,589.0
8/20/2023
00:00
8/20/2023
00:15
0.25 COMPZN, CASING RURD P Change out handling equipment to 5-
7/8" while topping string off with 10.1
mud.
12,589.0 12,589.0
8/20/2023
00:15
8/20/2023
00:45
0.50 COMPZN, CASING RUNL P RIH f/12,589' to 12,775' w/4.5" 12.6# /
P110 / HYD563 lower completion on 5-
7/8" DP. Fill with 10.1 ppg mud on the fly
and top off every 20 stands. Monitor
displacement on pit #5.
12,589.0 12,775.0
8/20/2023
00:45
8/20/2023
01:15
0.50 COMPZN, CASING SVRG P Service ST-120 while troubleshoot TDS
fault. Top off pipe fill.
12,775.0 12,775.0
8/20/2023
01:15
8/20/2023
06:00
4.75 COMPZN, CASING RUNL P RIH f/12,775' to 17,244' w/4.5" 12.6# /
P110 / HYD563 lower completion on 5-
7/8" DP. Fill with 10.1 ppg mud on the fly
and top off every 20 stands. Monitor
displacement on pit #5.
12,775.0 17,244.0
8/20/2023
06:00
8/20/2023
10:30
4.50 COMPZN, CASING RUNL P RIH f/17,244' to 19,750' at setting depth
w/4.5" 12.6# / P110 / HYD563 lower
completion on 5-7/8" DP. Fill with 10.1
ppg mud on the fly and top off every 20
stands. Monitor displacement on pit #5.
17,244.0 19,750.0
8/20/2023
10:30
8/20/2023
11:00
0.50 COMPZN, CASING RURD P L/D top single on stand # 133, r/u subs
for venting to mud manifold.
19,750.0 19,750.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 45/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/20/2023
11:00
8/20/2023
11:30
0.50 COMPZN, CASING PACK P Fill pipe at 150 gpm. Shear Arsenal
Floation Sub at 1,374 psi, pumped 10
strokes.
19,750.0 19,750.0
8/20/2023
11:30
8/20/2023
12:30
1.00 COMPZN, CASING PACK P Vent air bubble to mud manifold from
side entry sub for 15 min. Fill dry tubing
at 5 bpm w/108 bbls mud, slowed to 1
bpm at 530 psi.
19,750.0 19,750.0
8/20/2023
12:30
8/20/2023
13:00
0.50 COMPZN, CASING RURD P L/S subs and p/u single dp on stand #
133.
19,750.0 19,750.0
8/20/2023
13:00
8/20/2023
15:30
2.50 COMPZN, CASING PACK P Set liner on depth at 19,750'. Drop 1.25"
OD phenolic ball as per Baker rep.
Pump down at 3 bpm, 1,050 psi, 2960
stks. Ball on seat at 1,860 psi.
Pressured up to 2,500 psi to set Baker
SLZXP liner hanger, set down 40k to
verify set.
19,750.0 19,750.0
8/20/2023
15:30
8/20/2023
17:00
1.50 COMPZN, CASING PACK P Attempt to release HRD-E running tool
as per Baker rep. Pressured up to 3,800
psi, p/u to verify free travel,
unsuccessful. S/O to 80K and confirm
liner hanger is set.
19,750.0 19,750.0
8/20/2023
17:00
8/20/2023
19:30
2.50 COMPZN, CASING PACK T Drop 1.43" OD phenolic back up ball as
per Baker rep. Pump down w/ 50 bbls hi
-vis sweep and follow with 10.1 ppg mud
at 2.5 bpm, 1,700 psi, 2218 stks (with no
returns) when small pressure increased
observed. Cycled pumps and still no
good indication of ball is on the seat.
19,750.0 19,750.0
8/20/2023
19:30
8/20/2023
20:45
1.25 COMPZN, CASING PACK T Contact Anchorage and discussed plan
forward with team.
19,750.0 19,750.0
8/20/2023
20:45
8/20/2023
21:30
0.75 COMPZN, CASING PACK P Tested Baker liner top packer to 3,850
psi for 10 minutes. Pumped down kill
line against closed top rams and
recorder test on Totco IA pressure.
Good test. Bled off pressure and
opened top rams. Well static.
19,750.0 19,750.0
8/20/2023
21:30
8/20/2023
22:00
0.50 COMPZN, CASING PACK T P/U to 265K and confirmed HRD-E tool
was not released. Checked 2 times.
Performed mechanical release of Baker
HRD-E running tool as per Baker rep by
applying 1.75 turns left hand torque in
stages to 5k and working down to tool.
Slowly release trapped torque. Picked
up and verified that the HRD-E tool had
released, 208K st wt. S/O and reapplied
5k right hand torque to string. P/U and
pulled dog sub above TOL. Rotated at
20 rpm and S/O to 135k st wt with dog
sub to TOL. Confirmed packer was set.
No visual indication observed at surface.
TOL @ 12454.06', Shoe @ 19,750.00'
19,750.0 19,750.0
8/20/2023
22:00
8/21/2023
00:00
2.00 COMPZN, WELLPR DISP P PJSM. Displace well to 10.1 brine and
per Mud Engineer procedure at 12,421'.
12,421.0 12,421.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 46/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/21/2023
00:00
8/21/2023
02:00
2.00 COMPZN, WELLPR DISP P PJSM. Displace well to 10.1 ppg brine
and per Mud Engineer procedure at
12,421'. Total strokes pumped 8,033.
When spacers back at surface shakers
were 100% loaded with fines then
cleaned up once brine at surface. 50
bbls interface observed during
displacement.
Note: During displacement while
pumping spacers observed 2 pressure
spikes 24 minutes apart to ~3,824 psi
then dropped suddenly. Pressure
circulating prior was ~1780 psi and after
~1138 psi at 50 spm. These spikes
resemble each ball getting on seat then
shearing out.
GPM = 250
PSI = 952
12,421.0 12,421.0
8/21/2023
02:00
8/21/2023
02:15
0.25 COMPZN, WELLPR OWFF P Flow check - well static. 12,421.0 12,421.0
8/21/2023
02:15
8/21/2023
07:30
5.25 COMPZN, WELLPR TRIP P B/D top drive. POOH f/ 12,421' to
5,320'. L/D 23 joints 5-7/8" HWDP and
rack back stands DP. Monitor hole fill on
isolated pit #4.
12,421.0 5,320.0
8/21/2023
07:30
8/21/2023
07:45
0.25 COMPZN, WELLPR CIRC P Pump 30 bbl 11.6 ppg slug at 45 spm,
572 psi while changing to 4.5" handling
equipment.
5,320.0 5,320.0
8/21/2023
07:45
8/21/2023
10:00
2.25 COMPZN, WELLPR TRIP P POOH f/ 5,320' to surface racking back
stands DP. L/D Baker running tool. No
visual issues with running tool. Monitor
hole fill on isolated pit #4.
5,320.0 0.0
8/21/2023
10:00
8/21/2023
10:30
0.50 COMPZN, RPCOMP WWWH P M/U 2 joints 5" DP w/ FMC wear ring
reteriving tool. Pull wear ring as per
FMC rep.
0.0 0.0
8/21/2023
10:30
8/21/2023
14:00
3.50 COMPZN, RPCOMP WWWH P M/U stack wash tool w/1 stand 5-7/8"
DP. Wash stack at 1500 gpm. R/d same.
Clean OBM from drip pan.
SIMOPS: Mobilize casing equipment to
rig floor.
Crane ops: Remove drill line spool from
roof top and swap to new spool. Prep to
install new cable. Removed scud
launcher with crane from roof top for
upcoming rig move.
0.0 0.0
8/21/2023
14:00
8/21/2023
16:00
2.00 COMPZN, RPCOMP RURD P R/U casing running equipment. Mobilize
HES, Baker and SLB upper completion
tools to rig floor. Hang SLB sheave,
position control line spool, prep rig floor
for running tubing.
PJSM with crews for running upper
completion.
0.0 0.0
8/21/2023
16:00
8/22/2023
00:00
8.00 COMPZN, RPCOMP PUTB P RIH t/3,234' with 4-1/2" 12.6# / L80 /
HYD563 upper completion as per tally.
Torque to 3,600 ft/lbs. Top filling on the
fly and top off every 10 joints with brine.
Run LaSalle clamps on each
connection. Monitor SLB DHG reading
real time.
0.0 3,234.0
8/22/2023
00:00
8/22/2023
06:00
6.00 COMPZN, RPCOMP PUTB P RIH f/3,234' t/8,900' with 4-1/2" 12.6# /
L80 / HYD563 upper completion as per
tally. Torque to 3,600 ft/lbs. Top filling on
the fly and top off every 10 joints with
brine. Run LaSalle clamps on each
connection. Monitor SLB DHG reading
real time.
3,234.0 8,900.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 47/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/22/2023
06:00
8/22/2023
09:30
3.50 COMPZN, RPCOMP PUTB P RIH f/8,900' t/ TOL at 12,456' with 4-
1/2" 12.6# / L80 / HYD563 upper
completion as per tally. Torque to 3,600
ft/lbs. Top filling on the fly and top off
every 10 joints with brine. Run LaSalle
clamps on each connection. Monitor
SLB DHG reading real time.
8,900.0 12,456.0
8/22/2023
09:30
8/22/2023
10:15
0.75 COMPZN, RPCOMP PUTB P Set down 12K to shear locator sub as
per Baker rep. L/D joints # 299, 298,
297 and 296 for space out.
12,456.0 12,336.0
8/22/2023
10:15
8/22/2023
11:00
0.75 COMPZN, RPCOMP PUTB P M/U space outs pups, 7.63', 7.93', 9.72',
9.76' and P/U jt # 296.
12,336.0 12,406.0
8/22/2023
11:00
8/22/2023
12:00
1.00 COMPZN, RPCOMP THGR P M/U FMC tubing hanger w/2.85' pup jt
and landing joint as per FMC rep.
Terminate SLB TEC control line for DHG
to hanger. SLB tested control line -
good test. FMC test control line port on
hanger to 5,000 psi f/5 min - good test.
R/D SLB control line and sheave.
12,406.0 12,406.0
8/22/2023
12:00
8/22/2023
12:45
0.75 COMPZN, RPCOMP THGR P Drain stack. M/U landing jt pup, RIH and
land hanger, run in lock down pins as
per FMC rep.
P/U = 134K
S/O = 98K
BLK WT= 75K
12,406.0 12,456.0
8/22/2023
12:45
8/22/2023
14:30
1.75 COMPZN, RPCOMP PRTS P Pressure test tubing hanger seals
through kill line. Flood stack and choke
manifold with brine. Test tubing hanger
seals to 250 psi / 5 min and 4,000 psi /
10 min - good test. Charted test.
12,456.0 12,456.0
8/22/2023
14:30
8/22/2023
16:00
1.50 COMPZN, RPCOMP PRTS P R/U to pump down tubing and IA. Test
lines to 4,000 psi.
12,456.0 12,456.0
8/22/2023
16:00
8/22/2023
17:00
1.00 COMPZN, RPCOMP PRTS P Pressure up to 3,500 psi to set HES
TNT packer as per HES rep. Pumped
down tubing at 2 spm, 18 stks pumped.
Pressure test tubing for 30 min - good
test. Charted test and monitored IA
pressure.
12,456.0 12,456.0
8/22/2023
17:00
8/22/2023
18:45
1.75 COMPZN, RPCOMP PRTS P Bleed tubing to 2,500 psi. Pump down
IA at 5 spm, 70 stks pumped. Test
tubing hanger and IA to 3,800 psi for 30
min - good test. Charted test.
12,456.0 12,456.0
8/22/2023
18:45
8/22/2023
19:00
0.25 COMPZN, RPCOMP PRTS P Bleed tubing to zero rapidly to shear the
shear out valve. Pump 2 bpm, 1,124 psi
down IA and observed returns out tubing
indicating shear out valve sheared.
12,456.0 12,456.0
8/22/2023
19:00
8/22/2023
20:00
1.00 COMPZN, RPCOMP RURD P Flow check tubing - static, while r/d
pumping equipment and l/d landing joint.
0.0 0.0
8/22/2023
20:00
8/22/2023
21:00
1.00 COMPZN, RPCOMP PRTS P P/U t-bar and set FMC BPV in tubing
hanger as per FMC rep. L/D t-bar. Pump
down IA and pressure test BPV in
direction of flow to 2,500 psi f/ 10 min -
good test. Bled off to zero.
0.0 0.0
8/22/2023
21:00
8/23/2023
00:00
3.00 COMPZN, WHDBOP CLEN P Pump deep clean pill through mud
pumps 2,3,and 4, mpd system, top
drive, choke and mud manifolds, mgs
and flow line. Blow down all surface
lines for rig move.
0.0 0.0
8/23/2023
00:00
8/23/2023
06:00
6.00 COMPZN, WHDBOP NUND P PJSM, ND MPD Equip, ND BOP stack
and rack back. ND HP riser, clean
wellhead, SIMOPS: Blow down steam
system, clean pits, drip pan and pump
room sumps.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 48/48
CD4-586
Report Printed: 9/19/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/23/2023
06:00
8/23/2023
07:30
1.50 COMPZN, WHDBOP NUND P Prep wellhead for frac tree install.
SIMOPS: LD 4-1/2" DP from derrick via
90' MH.
0.0 0.0
8/23/2023
07:30
8/23/2023
08:15
0.75 COMPZN, WHDBOP NUND P SLB terminate Tec line through
wellhead. SIMOPS: LD 4-1/2" DP from
derrick via 90' MH.
0.0 0.0
8/23/2023
08:15
8/23/2023
10:30
2.25 COMPZN, WHDBOP NUND P Prep tree and wellhead for install. MU
10K frac tree as per FMC rep. Verify
orientation. Torque bolts to 1750 ft/lbs.
SIMOPS: LD 4-1/2" DP from derrick via
90' MH.
0.0 0.0
8/23/2023
10:30
8/23/2023
12:00
1.50 COMPZN, WHDBOP PRTS P Fill void with diesel. Notice leak at
DHVC sleeve, SLB tighten NPT fitting,
pressure up T/ 4200 psi, DHCV sleeve
leaking. Galled threads on fitting.
Replaced fitting. Conduct void test T/
5000 psi for 10 min ok witnessed by
CPAI rep. SIMOPS: LD 4-1/2" DP from
derrick via 90' MH.
0.0 0.0
8/23/2023
12:00
8/23/2023
16:00
4.00 COMPZN, WHDBOP PRTS P Fill tree with diesel, purge all valves, test
250 psi low for 5 min, 10,000 psi high for
15 min charted. SIMOPS: LD 4-1/2" DP
from derrick via 90' MH.
0.0 0.0
8/23/2023
16:00
8/23/2023
16:30
0.50 COMPZN, WHDBOP MPSP P Pull test dart and HP-BPV per FMC rep.
SIMOPS: LD 4-1/2" DP from derrick via
90' MH.
0.0 0.0
8/23/2023
16:30
8/23/2023
17:15
0.75 COMPZN, WHDBOP FRZP P RU to pump freeze protect with LRS.
SIMOPS: LD 4-1/2" DP from derrick via
90' MH.
0.0 0.0
8/23/2023
17:15
8/23/2023
18:00
0.75 COMPZN, WHDBOP PULD P LD 4-1/2" DP from derrick via 90' MH.
Continue cleaning pits.
0.0 0.0
8/23/2023
18:00
8/24/2023
00:00
6.00 COMPZN, WHDBOP FRZP P RU to to pump freeze protect, PJSM, PT
lines and equipment to 2500 psi with
LRS. Pump 103 bbls diesel freeze
protect down IA taking returns up tubing
at 1.25 bpm. Line up and U-Tube for 1
hr, suck lines, RD lines and equipment
0.0 0.0
8/24/2023
00:00
8/24/2023
02:00
2.00 COMPZN, WHDBOP MPSP P Cont RD equip, check pressures verify
tubing pressure 0 psi, set H-BPV per
FMC rep, remove secondary valves,
install flanges and gauges on
OA/IA/TBG, wipe down tree. Final
pressures OA=275 / IA=0 / Tbg=0
0.0 0.0
8/24/2023
02:00
8/24/2023
06:00
4.00 COMPZN, WHDBOP PULD P LD 4-1/2" and 5-7/8" DP from derrick
via 90' MH. Cont cleaning pits
0.0 0.0
8/24/2023
06:00
8/24/2023
13:00
7.00 COMPZN, WHDBOP PULD P LD 5-7/8" DP from derrick via 90' MH.
Prep CD4-539 cellar for mats, prep for
rig move
0.0 0.0
8/24/2023
13:00
8/24/2023
14:00
1.00 DEMOB, MOVE RURD P LD mouseholes and secure in pipe
shed, prep for move
0.0 0.0
8/24/2023
14:00
8/24/2023
15:00
1.00 DEMOB, MOVE RURD P Swap to gen power at 1400 hrs, fire up
moving gens, begin pre skid checklist,
electrician unplug, cont with
interconnects
0.0 0.0
8/24/2023
15:00
8/24/2023
16:30
1.50 DEMOB, MOVE RURD P Walk CPU away from pit mod, cont with
unplugging interconnects
0.0 0.0
8/24/2023
16:30
8/24/2023
18:00
1.50 DEMOB, MOVE RURD P Walk pipe shed away from sub, jack up
and stage on edge of pad w/ truck
Release rig at 1800 hrs
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 8/24/2023
Page 1/1
CD4-586
Report Printed: 9/19/2023
Cement
Cement Details
Description
Conductor String Cement
Cementing Start Date
3/24/2014 12:00
Cementing End Date
3/24/2014 14:00
Wellbore Name
CD4-586
Comment
Cement Stages
Stage # <Stage Number?>
Description
Conductor String Cement
Objective Top Depth (ftKB)
57.0
Bottom Depth (ftKB)
134.0
Full Return?
Yes
Vol Cement …Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) 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
Primary Cement
Fluid Description Estimated Top (ftKB)
58.0
Est Btm (ftKB)
134.0
Amount (sacks) Class Volume Pumped (bbl)
50.5
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Conductor String Cement
Page 1/1
CD4-586
Report Printed: 9/19/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
7/13/2023 18:30
Cementing End Date
7/13/2023 22:45
Wellbore Name
CD4-586
Comment
Pump surface cement job as per SLB program. Pump 5 bbls of water. Test lines to 3500 psi, good. Pump 100 bbls of 10.8 ppg spacer at 5 bpm, 100-87 psi. Batch
lead cement. Load bottom plug. Pump 377 bbls of 11.0 ppg lead cement at 5.5 bpm, 189-222 psi. Batch & pump 72 bbls of 15.8 ppg tail cement at 6 bpm, 492-
552 psi. Load top plug. Pump 20 bbls of water at 4.5 bpm, 306 psi. Swap to rig pump and displace cement with 376 bbls of 10.5 ppg mud at 6 bpm, 394-698 psi &
3 bpm, 450 psi. Plug bump with 376 bbls pumped and pressured up to 1000 psi, held for 5 minutes. Check floats, good. CIP 22:50 hrs. Lost returns with 335 bbls
of mud pumped on displacement. Total losses during cementing 42 bbls.
Cement Stages
Stage # 1
Description
Primary – Full Bore
Objective Top Depth (ftKB)
54.4
Bottom Depth (ftKB)
2,728.0
Full Return?
No
Vol Cement …
338.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
6
P Pump Final (psi)
495.0
P Plug Bump (psi)
450.0
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
Surface Cement
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
54.4
Est Btm (ftKB)
2,221.0
Amount (sacks)
1,108
Class
Blend
Volume Pumped (bbl)
377.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sack)
6.70
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
236.0
Thickening Time (hr)
7.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,221.0
Est Btm (ftKB)
2,728.0
Amount (sacks)
349
Class
G
Volume Pumped (bbl)
72.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.05
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
169.0
Thickening Time (hr)
4.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
CD4-586
Report Printed: 9/19/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
7/24/2023 17:00
Cementing End Date
7/24/2023 19:30
Wellbore Name
CD4-586
Comment
SLB PT lines to 4000 PSI, Pump 73.7 bbls 12.0 PPG mud push at 3.5 BPM, drop bottom plug, SLB pump 168.1 bbls 15.8 PPG cement at 5.4 BPM, 234-147 PSI,
drop top plug, SLB pump 20 bbls H2O.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective
Cement top to be 250'
TVD above shoe
Top Depth (ftKB)
5,747.0
Bottom Depth (ftKB)
7,800.9
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/…
6
P Pump Final (psi)
390.0
P Plug Bump (psi)
500.0
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)
5,747.0
Est Btm (ftKB)
7,801.0
Amount (sacks)
811
Class
G
Volume Pumped (bbl)
168.1
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
4.77
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
162.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
Page 1/1
CD4-586
Report Printed: 9/19/2023
Cement
Cement Details
Description
Intermediate String 2 Cement
Cementing Start Date
8/2/2023 03:00
Cementing End Date
8/2/2023 05:45
Wellbore Name
CD4-586
Comment
Blow air to cementers and fluid pack lines. Pressure test cement lines to 4000 psi. SLB batch and pump 40 bbls of 12.0 ppg mud push at 4 bpm, 515 psi. Citadel
release bottom dart. SLB pump 136 bbls 15.8 ppg class G cement at 4 bpm, 500 - 350 psi. Citadel release top dart. SLB pump 20 bbl fresh water at 4.5 bpm, 250
psi. Swap to rig mud pump #3. Displace cement with 9.2 ppg FWP at 4 bpm. At 160 strokes pumped slow rate to 2 bpm. Latch bottom wiper plug with 235 strokes
shear at 840 psi. Increase rate to 7 bpm. Decrease rate to 2 bpm at 1500 strokes and latch top wiper plug, sheared at 1710 psi. Increase rate to 7 bpm. At 2100
strokes shut off pumps and release BOZO plug. Increase rate to 7 bpm. At 2400 strokes reduce rate to 2 bpm. Land bottom wiper plug at 2471 strokes, shear at
2498 strokes with 2148 psi. Increase rate to 7 bpm. Slow to 6 bpm at 3297 strokes for ECD control. Slow to 2 bpm at 3800 strokes. Observe top wiper land on
landing collar at 3834 strokes, FCP 540 psi. Continue pumping to 1047 psi with 3837 stokes and hold 500 psi over FCP for 5 minutes. Check floats, holding.
Cement Stages
Stage # 1
Description
Liner Cement
Objective
1500' MD above the K3
top.
Top Depth (ftKB)
9,732.0
Bottom Depth (ftKB)
12,822.0
Full Return?
No
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
7
P Pump Final (psi)
540.0
P Plug Bump (psi)
1,047.0
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
Pump 40 bbls mup pus 2 drop bottom dart follwed by SLB pump 136 bbls 15.8 ppg class G cement. Drop top dart followed by 20 bbls of fresh water. switch to rig
and chase with 384 bbls 9.1 FWP. all darts and wipers latched and bumped as calculated, pressure up 500 psi over FCP of 540 psi for 1047 PSI and hold for 5
minutes. test floats and holding. Planned TOC 9732' MD. SonicScope log shows TOC at 9,326' MD.
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 2 Cement
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
CD4-586
9980 - 20736
3 Boxes
SENT BY: M. McCRACKEN
RECEIVED
AUG 3 1 2023
SAMPLE TRANSMITTAL
AOGCO
DATE: August 31, 2023
AIR BILL: N/A
CPAI: CPA12023083101
CHARGE CODE: N/A
NAME: CD4-586
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
13
11
2-
RECEIVED:
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7.If perforating:8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?CD4-586
Yes No
9.Property Designation (Lease Number):10. Field:
Colville De Narwhal Undefined Oil
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
20736 4364 20736 4364 1550 None None
Casing Collapse
Structural
Conductor
Surface 2260
Intermediate 5090
Production 4790, 11080
Liner 9210
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16.Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title: Completion Egnineer
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
baskoro.tejo@cop.com
Baskoro Tejo
907-265-6462
8/25/2023
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.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
11590
Tubing Grade: Tubing MD (ft):
LTP @ 12454' MD /4003' TVD, Production
Packer @ 12351' MD / 3988' TVD
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL384211, ADL380082, ADL380081, ADL391587
223-046
P.O. Box 100360 Anchorage, AK 99510-0360 50-103-20857-00-00
ConocoPhillips Alaska Inc.
Length Size
Proposed Pools:
L-80
TVD Burst
12460
6890, 12620
MD
8150
5020
135
2397
3442
135
2721
40577-5/8"
20" x 34"
13-3/8"
135
9-5/8"7801
2721
12822
Perforation Depth MD (ft):
7801
None
5181
4-1/2"
None
9/3/2023
197507296
4-1/2"
4364
Halliburton TNT Production Packer, Baker
SLZXP Liner Top Packer, no SSSV
Perforate
Repair Wepair Well
Exploratory Stratigraphic Development Service
BOP TestMechanical Integrity Test
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Comple
e foregoing gggg is true and
By Grace Christianson at 11:43 am, Aug 25, 2023
323-484
X
SFD 9/1/2023
10-404
CDW 9/1/2023
Fracture Stimulate
//
DSR-8/28/23VTL 9/1/23($8JLC 9/5/2023
09/05/23
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2023.09.05
13:02:41 -08'00'
RBDMS JSB 090823
Section 1 - Affidavit 10 AAC 25.283 (a)(1)
Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators
within one-half mile radius of the current or proposed wellbore trajectory have been provided
notice of operations in compliance with 20 AAC 25.283(a)(1).
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Table 1: Wells within 1/2 miles (2)(C)
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.”
Agree. SFD 8/30/2023
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.
Agree. SFD 8/30/2023
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.
TOC log 9326 ft MD CDW 9/1/23
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 07/13/2023 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 8.33
ppg water. Full returns were seen throughout the job. The plug bumped at 950 psi and the
floats were checked and they held.
9 & 5/8” casing cement pump report on 07/24/2023 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 890 psi and the floats
were checked and they held.
The 7 & 5/8” casing cement report on 08/02/2023 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 1047 psi and the
floats were checked and they held.
Summary
All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone
penetrated by the well is isolated.
Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has
determined that this well can be successfully fractured within its design limits.
SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO
PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE
WELL 20 AAC 25.283(a)(7)
On 07/15/2023 the 13-3/8” casing was pressure tested to 2,7700 psi for 30 minutes
On 07/24/2023 the 9-5/8” casing was pressure tested to 3,850 psi for 30 minutes.
On 08/4/2023 the 7-5/8” casing was pressure tested to 3,950 psi for 30 minutes.
On 08/22/2023 the 4-1/2” tubing was pressure tested to 3,500 psi for 30 minutes.
On 08/22/2023 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 280’ TVD thick at the heel of the lateral,
thickening to >900’ 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 12945.4’ MD, -4002.1’ TVDSS. The estimated fracture
gradient for the Narwhal reservoir is 10.9 ppg.
The overlying confining zone consists of greater than 1400’ TVD of Seabee Formation
(dominantly mudstones beginning at top of C-30, 2803.9’ MD, -2370.9’ TVDSS) and
approximately 225’ 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 CD4-586
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:
CD4-594: 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.
CD4-588: 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.
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.
CD4-301A: This well is targeting Nanuq Kuparuk, deeper than Narwhal. It has been plugged
and abandoned per state regulations on 12/30/2007.
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 CD4-586. The fault intersected the CD4-586 well
path at 6155’ 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
CD4-586, the fault was also encountered in the CD4-594 at 6297’ MD and CD4-588 at 6527’
MD. A second fault is seismically mapped within the one-half mile radius of the CD4-586
wellbore trajectory but was not intersected by the CD4-586; this fault was intersected in the
CD4-594 (estimated throw 10-15') within the half mile radius. This fault is seismically
interpreted to be confined within the Narwhal reservoir and does not intersect the confining
zones. The fault is shown on the Fault Plat map.
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 faults 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 CD4-586 wellbore.
Well Name
Fault
Depth MD
(ft)
Fault Depth
TVDSS (ft)
Fault Vertical
Displacement
(ft)
Fluid
Losses
(bbls/hr)
CD4-586 6155 -3158 60-90 0
CD4-588 6527 -2994 60-90 0
CD4-594 6297 -2888 60-90 0
CD4-594 16290 -4189 10-15 0
p,,,
one fault or fracture system transected the confining zone within oneyyg
half mile radius of the wellbore trajectory for CD4-586. The fault intersected the CD4-586 welljy
path at 6155’ MD and was interpreted from seismic data prior to drilling. The fault waspppg
encountered far above the r eservoir interval in the overlying Seabee Formation and interpreted
as a single plane with 60-90’ of throw. W
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
CD4-586 was completed in 2023 as a horizontal producer in the Narwhal formation. The well
was completed with a 4.5” tubing upper completion and a 4.5” liner with 11 ea ball actuated
and 6 ea dart actuated sliding sleeves lower completion. The 1st stage will be pumped with
initially dropping ball to shift sleeve opened, sequentially continue to remaining ball actuated
sleeves until stage 11 (progressively getting larger) after each remaining stage, these balls will
provide isolation from the previous stage and allow fracturing from the toe of the well towards
the heel. Stage 12-17 will be activated with dart drop system with the same mechanism as ball
drop.
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 2,000’ 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 and flowback
(Slickline and possibly CTU).
g
f 4,500 psi.
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
From:Loepp, Victoria T (OGC)
To:Operations Engineer, Doyon 26
Cc:Tejo, Baskoro
Subject:Re: [EXTERNAL]Re: CD4-586 Lower Completion Liner Top Packer Placement
Date:Saturday, August 19, 2023 7:56:54 PM
Thank you, placement of the LTP is approved.
Victoria
Sent from my iPhone
On Aug 19, 2023, at 4:40 PM, Operations Engineer, Doyon 26
<Doyon26.OperationsEngineer@conocophillips.com> wrote:
Hi Victoria,
Attached is the SLB log and interpretation for the SonicScope LWD log across the 7 5/8”
liner. Apparent top of cement is 9,326’ with good cement below 10,026’. Our planned
production packer placement is +/- 12,344’, so much greater than the frac regulation
requires below TOC.
Best Regards,
Scott
From: Operations Engineer, Doyon 26
Sent: Wednesday, August 16, 2023 11:15 AM
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Cc: Tejo, Baskoro <Baskoro.Tejo@conocophillips.com>
Subject: RE: [EXTERNAL]Re: CD4-586 Lower Completion Liner Top Packer Placement
Victoria,
The sonic data won’t be available until a few hours after we lay down the BHA. It will
take a few hours to download the data and then some additional time for
ConocoPhillips and Schlumberger to interpret the data. We plan to commence liner
running operations after the BHA is laid down and the LWD data is being downloaded
and processes.
The cement job on the 7 5/8” liner went well and we don’t expect any issues for the
10,026’.s 9,326’
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.
proposed packer setting depth. I’ve attached the cement summary previously sent for
your reference.
The current forecast is for laying down the BHA Saturday evening.
Best Regards,
Scott
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Sunday, August 13, 2023 7:17 PM
To: Operations Engineer, Doyon 26
<Doyon26.OperationsEngineer@conocophillips.com>
Cc: Tejo, Baskoro <Baskoro.Tejo@conocophillips.com>
Subject: [EXTERNAL]Re: CD4-586 Lower Completion Liner Top Packer Placement
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.
When will the Sonic results be available?
Sent from my iPhone
On Aug 13, 2023, at 12:36 PM, Operations Engineer, Doyon 26
<Doyon26.OperationsEngineer@conocophillips.com> wrote:
Hi Victoria,
We TD’d the lateral this morning and I wanted to follow up with you to
see if you have any questions on the request below.
Regards,
Scott
WSC Operations Engineer – Doyon 26
Scott Kolstad
26opseng@conocophillips.com
907.263.4552 (Office)
<image002.png>
From: Operations Engineer, Doyon 26
Sent: Monday, August 7, 2023 4:43 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Tejo, Baskoro <Baskoro.Tejo@conocophillips.com>; Winfree, Mike A
<Michael.A.Winfree@conocophillips.com>; Nagel, Matt B
<Matt.B.Nagel@conocophillips.com>; Metzgar, Kyle N
<Kyle.N.Metzgar@conocophillips.com>; Lee, David L
<David.L.Lee@conocophillips.com>; Montague, Justin D
<Justin.D.Montague@conocophillips.com>
Subject: CD4-586 Lower Completion Liner Top Packer Placement
Good afternoon Victoria,
This is to update you regarding the current status of CD4-586 and inform
you regarding the expected placement of the 4-1/2” lower completion
liner top packer.
CD4-586 Operational Update
As of August 7th, 2023 Doyon 26 has completed the intermediate 2 liner
and cement operations without issue. No losses occurred during the
cement operation and the plugs bumped according to designed pump
strokes. We are now beginning production drilling operations.
Current Wellbore Construction
1. Intermediate 2 Shoe: 12,822’ MD / 4,057’ TVD
2. Designed TOC: 9,732’ MD / 3,666’ TVD
CD4-586 Lower Completion Liner Top Design
1. Lower Completion Liner Top: 12,468’ MD / 4,005’ TVD (354’ MD
above the intermediate 2 shoe)
Similar to CD4-588, we designed the lower completion packer to be set
~354’ above the intermediate 2 shoe for the following reasons:
1. To ensure the liner top packer is set in an optimal sealing
environment, we plan to place it above the intermediate 2
shoetrack
1. The intermediate 2 shoetrack is longer than typical designs
at 295’ because the DrilQuip liner hanger system must be set
via cementing operation plug bump and subsequent
pressure up, the extended shoe track is to mitigate potential
over displacement of cement if the plug bump takes
additional strokes
2. A heavy heel is present in the intermediate 2 liner from 12,026’ to
12,527’ in which the lower completion packer must be set because
the well will be fracture stimulated
The above operations indicate the lower completion packer should be set
in pipe which has adequate cement behind it. Furthermore, we will be
processing our production hole SonicScope logs which evaluated the
intermediate 2 top of cement and will promptly send them to you once
they finish processing.
<image003.png>
If you have any questions please let me know.
Thank you,
WSC Operations Engineer – Doyon 26
Justin Brady
26opseng@conocophillips.com
907.263.4552 (Office)
<image002.png>
<CD4-586 7.625 sonic scope Top of cement interpretation SLB.pdf>
<CD4-586_SonicScope_Top_of_Cement_Service_RM_500MD.Pdf>
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
CRU CD4-586 (PTD No. 223-046; Sundry No. 323-484)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 1 September 1, 2023
(a) Application for
Sundry Approval (a)(1) Affidavit Provided with application. SFD
8/28/2023
(a)(2) Plat Provided with application. SFD
8/28/2023
(a)(2)(A) Well location
Provided with application. Well lies in Sections 19, 20, 29,
28, and 33 of T11N, R5E, UM.
SFD
8/28/2023
(a)(2)(B) Each water well within ½ mile
None: According to the Water Estate map available through
DNR’s Alaska Mapper application (accessed online August
28, 2023), there are no wells are used for drinking water
purposes are known to lie within ½ mile of the surface
location of CD4-586. There are no subsurface water rights
or temporary subsurface water rights within 17 miles of the
surface location of CD4-586.
SFD
8/28/2023
(a)(2)(C) Identify all well types within ½
mile
Provided with application. Comprehensive list of all wells
within Area of Review.
SFD
8/28/2023
(a)(3) Freshwater aquifers: geological
name; measured and true vertical depth
None. No freshwater is present per Finding 8 of AOGCC’s
Area Injection Order 18B, issued October 7, 2004, which
states that minimum values for formation water salinity in
the Colville delta Area range from 15,000 to 24,000 mg/l
total dissolved solids . As explained in (a)(2)(B), above, there
are no wells used for drinking water purposes within ½ mile
of the CD4-586 surface location. Per 20 AAC 25.990(27), (27)
"fresh-water" means water that (A) has a total dissolved
solids concentration of less than 10,000 mg/l, and occurs in a
stratum not exempted under 20 AAC 25.440; or (B) occurs in
a stratum that serves as a source of drinking water for
human consumption.
SFD
8/29/2023
(a)(4) Baseline water sampling plan None required: No freshwater aquifers present. SFD
8/29/2023
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
CRU CD4-586 (PTD No. 223-046; Sundry No. 323-484)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 2 September 1, 2023
(a)(5) Casing and cementing information
Provided with application. Proposed schematic attached, as
built not generated to date.
CDW
9/1/23
(a)(6) Casing and cementing operation
assessment
13-3/8” casing cement job went as planned.
9-5/8” casing cementing went as planned. TOC est as 6065
ft.
7-5/8” liner cementing went as planned. TOC est at 9732 ft
MD.
4.5” liner with swell packers.
CDW
9/1/23
(a)(6)(A) Casing cemented below
lowermost freshwater aquifer and
conforms to 20 AAC 25.030
Not Applicable: No freshwater aquifers present. (See
Section (a)(3), above.)
SFD
8/29/2023
(a)(6)( B) Each hydrocarbon zone is
isolated
Nanushuk Reservoir Interval: Yes. Tuluvak and Halo-
equivalent Intervals: No.
13-3/8” surface casing is set at 2,721’ MD (-2,354’ TVDSS)
and cemented with full returns and bumped plugs.
For CD4-586, 12-1/4” hole was drilled through the Tuluvak
and Halo sand intervals and 9-5/8” intermediate casing set
at 7,801’ MD (-3,396’ TVDSS). The plug bumped at 890 psi
and the floats were checked and held. The operator’s
calculated top of cement lies at 6,065’ MD (-3,145’ TVDSS),
which is below the Tuluvak and Halo intervals that extend
SFD
9/1/2023
SFD
9/1/2023
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
CRU CD4-586 (PTD No. 223-046; Sundry No. 323-484)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 3 September 1, 2023
from roughly 2,790’ MD to 5,500’ MD (-2,378’ to -3,076’
TVDSS).
The 7-5/8” casing shoe is set at 12,822’ MD, -3,983’ TVDSS.
Full returns were seen throughout the job. 136 barrels of
Class G 15.8 cement were pumped, and the plug bumped at
1047 psi and the floats held. The top of the Narwhal
reservoirs is 12,945’ MD (-4,002’ TVDSS). Assuming 30%
washout, volumetric calculations suggest the top of cement
lies at 9,543’ MD (-3,570’ TVDSS), so, cement isolates the
Nanushuk hydrocarbon-bearing interval.
(a)(7) Pressure test: information and
pressure-test plans for casing and tubing
installed in well
Provided with application.3850 psi MITIA planned, 3125 psi
MITT plan.
CDW
9/1/23
(a)(8) Pressure ratings and schematics:
wellbore, wellhead, BOPE, treating head
Provided with application. 10K psi wellhead max. frac.
Pressure 6125 psi. Pump knock out 6625 and GORV 7125
psi., lines test 8500 psi.
CDW
9/1/23
(a)(9)(A) Fracturing and confining zones:
lithologic description for each zone
(a)(9)(B) Geological name of each zone
(a)(9)(C) and (a)(9)(D) Measured and true
vertical depths
(a)(9)(E) Fracture pressure for each zone
Upper confining zones: Seabee Shale, consisting of
condensed mudstone , and Albian K3 siltstone that have
aggregate thicknesses of about 1,400’ and 225’ true vertical
thickness (TVT), respectively. Fracture gradient is expected
to range from about 0.73 to 0.88 psi/ft (14.2 to 17.0 ppg
EMW).
Fracturing Zone: Nanushuk “Narwhal” topset sands at
12,945’ MD (-4,002’ TVDSS). Fracture gradient is expected to
range from about 0.56 psi/ft (10.9 ppg EMW).
SFD
9/1/2023
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
CRU CD4-586 (PTD No. 223-046; Sundry No. 323-484)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 4 September 1, 2023
Lower confining zones: Albian-aged mudstone (not
penetrated by this horizontal well) that have an aggregate
TVT of about 250’. Fracture gradient expected to range from
about 0.83 to 0.88 psi/ft (16 to 17 ppg EMW).
(a)(10) Location, orientation, report on
mechanical condition of each well
Yes. The 2 wells are detailed. CDW
09/01/23
(a)(11) Sufficient information to determine
wells will not interfere with containment
within ½ mile
Yes. The 2 wells are detailed. CDW
09/01/23
(a)(11) Faults and fractures, Location,
orientation
(a)(11) Faults and fractures, Sufficient
information to determine no interference
with containment within ½ mile
Two faults: The operator has identified one 60- to 90-foot
fault that intersected the CD4-586 at 6155’ MD (-3,158’
TVDSS) that intersects the Seabee well above the fracturing
interval and is isolated from the fracturing interval by
cement. A second fault is mapped zones on seismic data
within a ½-mile radius of CD4-586. This 10- to 15-foot fault
is located about ¼ mile from the portion of CD4-586 that
will be fracture-stimulated, and it is restricted to the
Narwhal reservoir and does not intersect the confining
zones. It is unlikely that either of these faults will interfere
with containment of the injected fracturing fluids;
however, if there are indications that a fracture has
intersected a fault or natural-fracture interval during frac
operations, the operator will go to flush and terminate the
stage immediately.
SFD
9/1/2023
(a)(12) Proposed program for fracturing
operation
Provided with application. CDW
09/01/2023
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
CRU CD4-586 (PTD No. 223-046; Sundry No. 323-484)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 5 September 1, 2023
(a)(12)(A) Estimated volume Provided with application. 26000 bbl CDW
09/01/2023
(a)(12)(B) Additives: names, purposes,
concentrations
Provided with application. CDW
09/01/2023
(a)(12)(C) Chemical name and CAS
number of each
Provided with application. Reslink and HES chems provided.
Confidential disclosures on file .
CDW
09/01/2023
(a)(12)(D) Inert substances , weight or
volume of each
Provided with application. 2.2Million lb CDW
09/01/2023
(a)(12)(E) Maximum treating pressure with
supporting info to determine
appropriateness for program
Simulation shows max surface pressure 4500 psi. Max.
6125 psi allowable treating pressure identified by CPAI.
Max pressure is 6625-7125 to Pump shutdown. With 3500
psi back pressure IA (IA popoff set 3600 psi), max tubing
differential should be between 1000 and 2625 psi.
CDW
09/01/2023
(a)(12)(F) Fractures – height, length, MD
and TVD to top, description of fracturing
model
Provided with application. The anticipated half-lengths of
the induced fractures are 350 to 850’ according to the
Operator’s computer simulation. Computer simulation
indicates the anticipated height of the induced fractures will
be about 4,093’ TVD and the heights will range from 85’ to
120’). Fracture gradients of the overlying confining layer
will not be exceeded during stimulation operations, but if
they do, the induced fractures may penetrate into, but not
through, the overlying confining intervals.
SFD
9/1/2023
(a)(13) Proposed program for post-
fracturing well cleanup and fluid recovery
Well cleanout and flowback procedure provided with
application. No disposal identified
CDW
09/01/2023
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
CRU CD4-586 (PTD No. 223-046; Sundry No. 323-484)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 6 September 1, 2023
(b)Testing of casing
or intermediate
casing
Tested >110% of max anticipated pressure
3500 psi back pressure, plan to test to 3850 psi, popoff set
as 3600 psi
CDW
09/01/2023
(c) Fracturing string (c)(1) Packer >100’ below TOC of
production or intermediate casing
4.5” tubing will be anchored with a production packer at
12851 ft. 4.5” liner set from 12454. 7-5/8” liner TOC est by
log as 9326 with good cement from 10,000 ft to shoe.
CDW
09/01/2023
(c)(2) Tested >110% of max anticipated
pressure differential
Tubing test of 3125 psi. Max pressure differential is
estimated as 2625 psi (6125 with 3500 psi backpressure) so
test of 3125 psi satisfies 110%
CDW
09/01/2023
(d) Pressure relief
valve
Line pressure <= test pressure, remotely
controlled shut-in device
8500 psi line pressure test, pump knock out 6625 and
global kickout 7125 psi. IA PRV set as 3600 psi.
CDW
09/01/2023
(e) Confinement Frac fluids confined to approved
formations
Provided with application. CDW
09/01/2023
(f) Surface casing
pressures
Monitored with gauge and pressure relief
device
IA PRV set at 3600 psi. Surface annulus open. Frac
pressures continuously monitored.
CDW
09/01/2023
(g) Annulus
pressure
monitoring &
notification
500 psi criteria
During hydraulic fracturing operations, all annulus pressures
must be continuously monitored and recorded. If at any
time during hydraulic fracturing operations the annulus
pressure increases more than 500 psig above those
anticipated increases caused by pressure or thermal
transfer, the operator shall:
CDW
09/01/2023
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
CRU CD4-586 (PTD No. 223-046; Sundry No. 323-484)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 7 September 1, 2023
(g)(1) Notify AOGCC within 24 hours
(g)(2) Corrective action or surveillance
(g)(3) Sundry to AOGCC
(h) Sundry Report
(i) Reporting (i)(1) FracFocus Reporting
(i)(2) AOGCC Reporting: printed &
electronic
(j) Post-frac water
sampling plan Not required (see Section (a)(3), above), SFD
9/1/2023
(k) Confidential
information
Clearly marked and specific facts
supporting nondisclosure Confidential exploratory well. SFD
9/1/2023
(l) Variances
requested
Modifications of deadlines, requests for
variances or waivers
No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________COLVILLE RIV UNIT CD4-586
JBR 09/12/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:2
Tested all gas alarms and PVT's, tested with 7 5/8" and 4 1/2" test joints. Test Annular w/ 7-5/8" TJ to 250/2500psi; test Annular
w/ 4-1/2" TJ to 250/3500psi. Manual valve was serviced and passed retest, UPR on the 4 1/2" tested joint was functioned and
passed retest. Precharge Bottles = 36 each all at 1000psi each.
Test Results
TEST DATA
Rig Rep:R. Pankratz / A. AgnesOperator:ConocoPhillips Alaska, Inc.Operator Rep:M. Wiens / A. Lundale
Rig Owner/Rig No.:Doyon 26 PTD#:2230460 DATE:7/15/2023
Type Operation:DRILL Annular:
250/3500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopBDB230717091803
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 10
MASP:
1485
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 2 P
Inside BOP 2 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 4 1/2"x 7 5/8"FP
#2 Rams 1 Blind/Shear P
#3 Rams 1 4 1/2"x 7 5/8"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"FP
HCR Valves 2 3 1/16", 3 1/8 P
Kill Line Valves 2 3", 3-16"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P2900
Pressure After Closure P1700
200 PSI Attained P28
Full Pressure Attained P88
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P10@3900
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P17
#1 Rams P10
#2 Rams P11
#3 Rams P13
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9
9
9999
9
9
9
9
7HVWFKDUWVDWWDFKHG MEU
FP
FP
Manual valve was serviced UPR on the 4 1/2" tested joint
&58&' 37'
$2*&&,QVS5SWERSEGE
&58&' 37'
$2*&&,QVS5SWERSEGE
&58&' 37'
$2*&&,QVS5SWERSEGE
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 20,736 feet feet
true vertical 4,364 feet feet
Effective Depth measured 20,736 feet 12,454 / 12,351 feet
true vertical 4,364 feet 4,003 / 3,988 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 12,460' MD 4,003' TVD
SLZXP LTP 12,454' MD 4,003' TVD
Packers and SSSV (type, measured and true vertical depth) HAL TNT 12,351' MD 3,988' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Baskoro Tejo
Contact Email:Baskoro.Tejo@conocophillips.com
Authorized Title:Completion Engineer Contact Phone:907-265-6462
2721 2397
Burst Collapse
2260
5090
4790, 11080
5020
8150
6890, 12620
measured
TVD
Production
Liner
7801
5181
7296
Casing
Structural
3442
4057
4-1/2"
7801
12822
19,750 4364
Plugs
Junk measured
2.221 MMlbs 20/40 Wan-Li Ceramic proppant, 75,000 lbs of 100 Mesh, 1344 gallons of seawater, and 2900 psi treating pressure/3200 psi BHG pressure.
Length
135
2721
135Conductor
Surface
Intermediate
20"
13-3/8"
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL384211, ADL380082, ADL380081, ADL391587
Colville Delta - Narwhal Undefined Oil
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-046
50-103-20857-00-00
Size
135
9-5/8"
11590
7-5/8"
P.O. Box 100360 Anchorage, AK 99510-03603. Address:
CD4-586
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Gas-Mcf
MD
13,576' - 19,576' MD
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
323-484
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.
Development Service
GINJ SUSP SPLUG
Gas
WINJ WAG
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Colville Delta - Narwhal Undefined Oil
By Grace Christianson at 8:11 am, Sep 13, 2023
Prepared By:
Keegan Lambe
Daniel Faur
Nanook Crew
Intervals 1-17 Narwhal
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 users
own risk.
CD4-586
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20857
Prepared for: Baskoro Tejo
September 6, 2023
Narwal Formation
30# Delta
Table of Contents
Section Page(s)
Executive Summary
Wellbore Information
Actual Design
Interval Summary
Fluid System-Proppant Summary
Interval 1 Plots
Interval 2 Plots
Interval 3 Plots
Interval 4 Plots
Interval 5 Plots
Interval 6 Plots
Interval 7 Plots
Interval 8 Plots
Interval 9 Plots
Interval 10 Plots
Interval 11 Plots
Interval 12 Plots
Interval 13 Plots
Interval 14 Plots
Interval 15 Plots
Interval 16 Plots
Interval 17 Plots
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 9-3
Water Straps 9-4
Water Straps 9-5
Water Straps 9-6
Water Analysis 9-2
Water Analysis 9-4
Water Analysis 9-5
Water Analysis 9-6
Real-Time QC
Event Log 9-3
Event Log 9-4
Event Log 9-5
Event Log 9-6
Prejob Break Test
Fann 15 Min Test Interval 1
Fann 15 Min Test Interval 2
Fann 15 Min Test Interval 3
Fann 15 Min Test Interval 4
Fann 15 Min Test Interval 5
Fann 15 Min Test Interval 6
Fann 15 Min Test Interval 7
Fann 15 Min Test Interval 8
Fann 15 Min Test Interval 9
Fann 15 Min Test Interval 10
Fann 15 Min Test Interval 11
Fann 15 Min Test Interval 12
Fann 15 Min Test Interval 13
Fann 15 Min Test Interval 14
Fann 15 Min Test Interval 15
Fann 15 Min Test Interval 16
Fann 15 Min Test Interval 17
Lab Testing
160
161
162
163
155
156
157
158
159
150
151
152
153
154
145
146
147
148
149
140
141
142
143
144
135
136
137
138
139
127
128 - 131
132
133
134
109 - 116
117 - 120
121 - 124
125
126
81 - 84
85 - 92
93 - 96
97 - 100
101 - 104
105 - 108
3
4
5 - 8
53 - 56
57 - 60
61 - 68
9 - 32
33
34 - 48
49 - 52
69 - 72
73 - 76
77 - 80
Conoco Phillips - CD4-586 TOC 2
816,020 gallons of 30# Delta Frac
114,263 gallons of 30# Linear
4,000 gallons of Seawater
0 gallons of Freeze Protect
2,210,000 pounds of Wanli 20/40 Ceramic
68,000 pounds of 100M
866,880 gallons of 30# Delta Frac
91,739 gallons of 30# Linear
1,344 gallons of Seawater
2,220,900 pounds of Wanli 20/40 Ceramic
75,000 pounds of 100M
Thank you,
Keegan Lambe
Senior Technical Professional
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 September 03, 2023 a stimulation treatment was performed in the Narwal formation on the CD4-586 well in Harrison Bay
County, AK. The CD4-586 was a 17 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 16 of 17 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:
MO-67 was diluted at a 1:4 ratio to optimize delivery rates while pumping. After the initial dart interval darts were dropped in
crosslink per CoP representative.
During the end of interval 10 8ppg stage the crosslink fluids started to show signs of a weaker fluid. 8ppg stage was pumped to
completion, ball was dropped and crosslink was attempted to be re-established. After crosslink could not be re-established the
ball was seated. Determined that two of the tanks, when run individually and as a pair rendered the crosslink unstable. Tested
with starting chemicals and then fresh chemicals from unopened totes. These tanks were tagged out. Crosslink was re-
established and the day was resumed pumping with no further issues.
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.
Interval 17 was cut short of design. Sand operator called out on last bin when in 4ppg, design was adjusted based off estimated
40,000lbs remaining. All proppant pumped from castles.
Conoco Phillips - CD4-586 Executive Summary 3
Conoco Phillips
Narwhal
CD4-586
50-103-20857
*Exceeds 80% of burst pressure*
Description OD (in) ID (in) Wt (#) Grade
FUF
(gal/ft)
MD Top
(ft)MD Btm (ft) Volume (gal)
Tubular Burst
Pressure (psi)
Tubing 4.5 3.958 12.6 L-80 0.6392 0 12,451 7,959 8,430
Tubing 4.5 3.958 12.6 L-80 0.6392 12,451 20,736 5,296 8,430
Total 20,736 13,254
ft 0.80
ft 95.0
ft
ft 0.80
ft 95.0
ft
Top MD
(ft)Btm MD (ft)Average
TVD (ft)Interval #Formation Descriptor Average 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)
BH Seat
Pressure
(psi)
BH Peak
Pressure
(psi)
BH
Differential
(psi)
Rate at Shift
(bpm)
Toe 19,576 19,580 4,360 1 Narwhal 94.9 8:10:00 AM 8:24:00 AM 38.5 286 333.6 2.82 1688 4779 3091 3048 5854 2,806 12.67
19,178 19,182 4,370 2 Narwhal 95.0 11:25:00 AM 11:39:00 AM 2,749 2,991 3,045 -4.1 3,204 6,243 3,039 3,645 6,910 3,265 12.0
18,823 18,827 4,371 3 Narwhal 95.0 12:29:00 PM 12:42:00 PM 4,244 4,480 4,536 -5.5 3,192 6,020 2,828 3,504 6,420 2,916 11.8
18,425 18,429 4,368 4 Narwhal 94.9 1:34:00 PM 1:47:00 PM 5,802 6,032 6,082 0.4 2,465 5,457 2,992 3,168 6,395 3,227 12.7
18,028 18,032 4,355 5 Narwhal 94.8 7:11:00 AM 7:30:00 AM 22 246 296 0.8 2,271 5,886 3,615 2,813 6,396 3,583 12.0
17,675 17,679 4,339 6 Narwhal 94.7 8:20:00 AM 8:33:00 AM 1,514 1,733 1,786 -3.0 2,737 5,804 3,067 3,316 6,610 3,294 12.1
17,278 17,282 4,328 7 Narwhal 94.6 9:18:00 AM 9:30:00 AM 2,875 3,088 3,138 -0.1 2,445 5,519 3,074 3,106 6,402 3,296 11.9
16,880 16,884 4,301 8 Narwhal 94.4 10:08:00 AM 10:20:00 AM 4,038 4,245 4,296 -1.1 2,613 5,695 3,082 3,150 6,272 3,122 12.4
16,524 16,528 4,285 9 Narwhal 94.3 10:59:00 AM 11:11:00 AM 5,236 5,437 5,490 -2.5 2,444 5,404 2,960 3,096 5,668 2,572 11.9
16,127 16,131 4,274 10 Narwhal 94.2 7:03:00 AM 7:19:00 AM 27 222 270 2.0 1,566 4,767 3,201 2,971 6,159 3,188 12.2
15,729 15,733 4,263 11 Narwhal 94.1 8:14:00 AM 8:26:00 AM 1,611 1,800 1,837 13.4 1,306 4,666 3,360 2,790 6,108 3,318 12.2
15,378 15,382 4,253 12 Narwhal 94.0 11:18:00 AM 11:27:00 AM 3,329 3,513 3,552 11.0 1,993 1,940 3,017 3,079 62 18.5
14,985 14,988 4,237 13 Narwhal 93.9 12:29:00 PM 12:40:00 PM 4,900 5,078 5,125 3.1 2,496 2,666 170 3,004 3,191 187 12.2
14,590 14,593 4,221 14 Narwhal 93.8 1:19:00 PM 1:29:00 PM 6,053 6,225 6,270 5.0 2,150 2,153 3 2,883 2,818 11.1
14,239 14,242 4,217 15 Narwhal 93.7 7:01:00 AM 7:16:00 AM 22 189 233 6.1 2,015 2,609 594 2,822 3,341 519 12.0
13,929 13,932 4,210 16 Narwhal 93.7 8:00:00 AM 8:10:00 AM 1,325 1,487 1,534 3.0 2,152 3,804 1,652 2,858 4,196 1,338 11.9
Heel 13,576 13,580 4,178 17 Narwhal 93.4 8:54:00 AM 9:04:00 AM 2,596 2,753 2,803 -0.4 2,227 2,230 3 2,853 2,889 36 12.7
212.0
206.6
262.9
256.9
251.5
245.4
239.4
234.0
8,678
9,830
9,578
9,326
9,101
8,903
11,044
10,790
10,562
10,308
10,054
12,032 286.5
11,778
11,523
11,298
Displacement to Top
Sleeve/Perf (gal)(BBLS)
12,513 297.9
12,259 291.9
280.4
274.4
269.0
Interval #
1
Max Pressure (psi)
7,500
Isolation Type
Swell Packer
Treatment Tubulars
Customer
Formation
Lease
API
Date
Temperature Data
Temp. Gradient (°F/100 ft)
BHST (°F)
Directional Data
4,290
2,237
20,736
Directional Data
2,237
9/3/2023
KOP
Temperature Data
Sleeve/Perf Depth Sleeves
228.1
222.0
216.7
7
8
9
10
11
2
3
4
5
6
17
12
13
14
15
16
Temp. Gradient (°F/100 ft)
BHST (°F)TVD at Bottom Perf
MD at Bottom Perf
4,371
19,580
KOP
Avg. TVD
Total MD
Conoco Phillips - CD4-586 Wellbore Information 4
CUSTOMER Conoco Phillips API BFD (lb/gal)8.54 LAT 70.29234487
LEASE CD4-586 SALES ORDE BHST (°F)95 LONG -150.9872544
FORMATION Narwhal DATE Max Pressure (psi)7500 *Exceeds 80% of burst pressure*
Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer
Interval 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 Seawater Prime Up Pressure Test 5.0 1,000 294 7 7 0.15
1-3 Shut-In Shut-In -
1-4 30# Linear Arsenal Sleeve Shift 5.0 1,260 154 4 4 1.00 30.00 1.50 0.15
1-5 30# Linear Spacer and Ball Drop 15.0 1,260 1,528 36 36 1.00 30.00 1.50 0.15
1-6 30# Linear Displace Ball to Seat 15.0 12,513 12,701 302 302 1.00 30.00 1.50 0.15
1-7 30# Linear DFIT 12.0 2,016 2,121 51 51 1.00 30.00 1.50 0.15
1-8 Shut-In Shut-In -
1-9 30# Linear Step Rate Test 15.0 8,400 4,010 95 95 1.00 30.00 1.50 0.15
1-10 30# Delta Frac Minifrac - Establish Fluid 25.0 8,400 6,397 152 152 0.50 1.00 0.25 30.00 1.50 0.15
1-11 30# Delta Frac Minifrac - Treatment 25.0 6,300 6,635 158 158 0.50 1.00 0.25 30.00 1.50 0.15
1-12 30# Linear Minifrac - Flush 25.0 12,513 12,653 301 301 1.00 30.00 1.50 0.15
1-13 Shut-In Shut-In -
1-14 30# Delta Frac Establish Stable Fluid 15.0 8,400 2,375 57 57 0.50 1.00 0.30 30.00 1.50 0.15
1-15 30# Delta Frac Pad 25.0 10,000 10,180 242 242 0.50 1.00 0.30 30.00 1.50 0.15
1-16 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 10,000 12,903 307 312 5,000 4,604 0.50 1.00 0.30 30.00 1.50 0.15
1-17 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 4,500 4,510 107 112 4,500 4,604 0.50 1.00 0.30 30.00 1.50 0.15
1-18 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 4,500 4,533 108 117 9,000 8,137 0.50 1.00 0.30 30.00 1.50 0.15
1-19 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 5,500 5,489 131 147 16,500 15,637 0.50 1.00 0.30 30.00 1.50 0.15
1-20 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 7,000 6,994 167 197 28,000 28,424 0.50 1.00 0.30 30.00 2.00 0.15
1-21 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,200 7,205 172 210 36,000 36,273 0.50 1.00 0.30 30.00 2.00 0.15
1-22 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,000 7,681 183 225 36,000 39,590 0.50 1.00 0.30 30.00 2.00 0.15
1-23 30# Delta Frac Spacer and Ball Drop 15.0 1,260 1,510 36 36 0.50 1.00 0.30 30.00 2.00 0.15
2-1 30# Delta Frac Pad 25.0 10,000 9,835 234 234 0.50 1.00 0.30 30.00 1.50 0.15
2-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 9,835 234 238 4,000 3,989 0.50 1.00 0.30 30.00 1.50 0.15
2-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 4,500 4,501 107 111 4,500 3,918 0.50 1.00 0.30 30.00 1.50 0.15
2-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 4,500 4,500 107 116 9,000 8,600 0.50 1.00 0.30 30.00 1.50 0.15
2-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 5,500 5,513 131 148 16,500 15,988 0.50 1.00 0.30 30.00 1.50 0.15
2-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 7,000 7,142 170 200 28,000 28,063 0.50 1.00 0.30 30.00 2.00 0.15
2-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,200 7,193 171 210 36,000 36,098 0.50 1.00 0.30 30.00 2.00 0.15
2-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,000 7,407 176 217 36,000 38,236 0.50 1.00 0.30 30.00 2.00 0.15
2-9 30# Delta Frac Spacer and Ball Drop 15.0 1,260 1,332 32 32 0.50 1.00 0.30 30.00 2.00 0.15
3-1 30# Delta Frac Pad 25.0 10,000 10,318 246 246 0.50 1.00 0.30 30.00 1.50 0.15
3-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 11,240 268 273 4,000 4,535 0.50 1.00 0.30 30.00 1.50 0.15
3-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 4,500 4,498 107 112 4,500 4,327 0.50 1.00 0.30 30.00 1.50 0.15
3-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 4,500 4,509 107 116 9,000 8,580 0.50 1.00 0.30 30.00 1.50 0.15
3-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 5,500 5,810 138 157 16,500 17,317 0.50 1.00 0.30 30.00 1.50 0.15
3-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 7,000 7,006 167 196 28,000 27,887 0.50 1.00 0.30 30.00 2.00 0.15
3-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,200 7,199 171 209 36,000 35,360 0.50 1.00 0.30 30.00 2.00 0.15
3-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,000 7,580 180 221 36,000 38,448 0.50 1.00 0.30 30.00 2.00 0.15
3-9 30# Delta Frac Spacer and Ball Drop 15.0 1,260 1,294 31 31 0.50 1.00 0.30 30.00 2.00 0.15
4-1 30# Delta Frac Pad 25.0 8,000 7,492 178 178 0.50 1.00 0.30 30.00 1.50 0.15
4-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,922 212 216 4,000 3,735 0.50 1.00 0.30 30.00 1.50 0.15
4-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,023 72 76 3,000 3,735 0.50 1.00 0.30 30.00 1.50 0.15
4-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,003 72 78 6,000 5,801 0.50 1.00 0.30 30.00 1.50 0.15
4-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,500 3,494 83 94 10,500 10,116 0.50 1.00 0.30 30.00 1.50 0.15
4-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,000 5,125 122 144 20,000 20,355 0.50 1.00 0.30 30.00 2.00 0.15
4-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,200 5,196 124 152 26,000 26,814 0.50 1.00 0.30 30.00 2.00 0.15
4-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,500 5,504 131 166 33,000 32,825 0.50 1.00 0.30 30.00 2.00 0.15
4-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,500 6,489 155 191 31,500 34,636 0.50 1.00 0.30 30.00 2.00 0.15
4-10 30# Linear Flush 25.0 11,778 11,941 284 284 1.00 30.00 2.00 0.15
4-11 Shut-In Shut-In -
50-103-20857
908818284
Liquid Additives Dry Additives
Interval 1Narwhal@ 19575.78 - 19579.64 ft 94.9 °FInterval 2Narwhal@ 19178.32 - 19182.18 ft 95 °FInterval 3Narwhal@ 18822.79 - 18826.65 ft 95 °FInterval 4Narwhal@ 18425.45 - 18429.31 ft 94.9 °FConoco Phillips - CD4-586 Actual Design 5
CUSTOMER Conoco Phillips API BFD (lb/gal)8.54 LAT 70.29234487
LEASE CD4-586 SALES ORDE BHST (°F)95 LONG -150.9872544
FORMATION Narwhal DATE Max Pressure (psi)7500 *Exceeds 80% of burst pressure*
Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)
50-103-20857
908818284
Liquid Additives Dry Additives
5-1 Shut-In Shut-In -
5-2 Seawater Prime Up Pressure Test 5.0 1,000 336 8 8 0.15
5-3 Shut-In Shut-In -
5-4 30# Linear Spacer and Ball Drop 15.0 1,260 1,401 33 33 1.00 30.00 1.50 0.15
5-5 30# Delta Frac Establish Stable Fluid 15.0 8,400 5,003 119 119 0.50 1.00 0.30 30.00 1.50 0.15
5-6 30# Delta Frac Pad 25.0 8,000 8,326 198 198 0.50 1.00 0.30 30.00 1.50 0.15
5-7 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 10,254 244 249 4,000 4,288 0.50 1.00 0.30 30.00 1.50 0.15
5-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,025 72 74 3,000 2,190 0.50 1.00 0.30 30.00 1.50 0.15
5-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,025 72 78 6,000 5,367 0.50 1.00 0.30 30.00 1.50 0.15
5-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,500 3,504 83 94 10,500 10,399 0.50 1.00 0.30 30.00 1.50 0.15
5-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,000 5,347 127 149 20,000 20,574 0.50 1.00 0.30 30.00 2.00 0.15
5-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,200 5,218 124 151 26,000 25,399 0.50 1.00 0.30 30.00 2.00 0.15
5-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,500 5,500 131 166 33,000 32,821 0.50 1.00 0.30 30.00 2.00 0.15
5-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,500 6,133 146 182 31,500 33,906 0.50 1.00 0.30 30.00 2.00 0.15
5-15 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,304 31 31 0.50 1.00 0.30 30.00 2.00 0.15
6-1 30# Delta Frac Pad 25.0 8,000 7,914 188 188 0.50 1.00 0.30 30.00 1.50 0.15
6-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 11,433 272 277 4,000 4,282 0.50 1.00 0.30 30.00 1.50 0.15
6-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,006 72 74 3,000 2,045 0.50 1.00 0.30 30.00 1.50 0.15
6-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,001 71 77 6,000 5,612 0.50 1.00 0.30 30.00 1.50 0.15
6-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,500 3,477 83 94 10,500 10,977 0.50 1.00 0.30 30.00 1.50 0.15
6-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,000 5,024 120 142 20,000 20,787 0.50 1.00 0.30 30.00 2.00 0.15
6-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,200 5,206 124 152 26,000 26,079 0.50 1.00 0.30 30.00 2.00 0.15
6-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,500 5,502 131 166 33,000 33,070 0.50 1.00 0.30 30.00 2.00 0.15
6-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,500 5,394 128 159 31,500 28,547 0.50 1.00 0.30 30.00 2.00 0.15
6-10 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,349 32 32 0.50 1.00 0.30 30.00 2.00 0.15
7-1 30# Delta Frac Pad 25.0 3,500 3,468 83 83 0.50 1.00 0.30 30.00 1.50 0.15
7-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,594 205 207 4,000 2,604 0.50 1.00 0.30 30.00 1.50 0.15
7-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,707 64 67 2,500 2,222 0.50 1.00 0.30 30.00 1.50 0.15
7-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,543 61 65 5,000 4,301 0.50 1.00 0.30 30.00 1.50 0.15
7-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,262 78 87 9,750 8,817 0.50 1.00 0.30 30.00 1.50 0.15
7-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,602 110 130 18,400 18,996 0.50 1.00 0.30 30.00 2.00 0.15
7-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,922 117 144 24,600 25,454 0.50 1.00 0.30 30.00 2.00 0.15
7-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,497 107 137 27,000 27,762 0.50 1.00 0.30 30.00 2.00 0.15
7-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,266 78 103 22,750 23,352 0.50 1.00 0.30 30.00 2.00 0.15
7-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,714 88 110 20,000 20,638 0.50 1.00 0.30 30.00 2.00 0.15
7-11 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,275 30 30 0.50 1.00 0.30 30.00 2.00 0.15
8-1 30# Delta Frac Pad 25.0 3,500 3,426 82 82 0.50 1.00 0.30 30.00 1.50
8-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 9,636 229 234 4,000 3,899 0.50 1.00 0.30 30.00 1.50 0.15
8-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 3,019 72 74 2,500 2,135 0.50 1.00 0.30 30.00 1.50 0.15
8-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,564 61 66 5,000 4,519 0.50 1.00 0.30 30.00 1.50 0.15
8-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,251 77 88 9,750 9,522 0.50 1.00 0.30 30.00 1.50 0.15
8-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,610 110 130 18,400 18,715 0.50 1.00 0.30 30.00 2.00 0.15
8-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,921 117 143 24,600 24,125 0.50 1.00 0.30 30.00 2.00 0.15
8-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,519 108 138 27,000 28,419 0.50 1.00 0.30 30.00 2.00 0.15
8-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,265 78 102 22,750 22,615 0.50 1.00 0.30 30.00 2.00 0.15
8-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,833 91 114 20,000 21,848 0.50 1.00 0.30 30.00 2.00 0.15
8-11 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,405 33 33 0.50 1.00 0.30 30.00 2.00 0.15
9-1 30# Delta Frac Pad 25.0 3,500 4,302 102 102 0.50 1.00 0.30 30.00 1.50 0.15
9-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 7,981 190 192 4,000 2,093 0.50 1.00 0.30 30.00 1.50 0.15
9-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,498 59 62 2,500 2,134 0.50 1.00 0.30 30.00 1.50 0.15
9-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,519 60 65 5,000 5,119 0.50 1.00 0.30 30.00 1.50 0.15
9-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,284 78 89 9,750 10,069 0.50 1.00 0.30 30.00 1.50 0.15
9-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,641 111 131 18,400 19,167 0.50 1.00 0.30 30.00 2.00 0.15
9-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,927 117 144 24,600 25,020 0.50 1.00 0.30 30.00 2.00 0.15
9-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,500 107 133 27,000 24,622 0.50 1.00 0.30 30.00 2.00 0.15
9-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,253 77 101 22,750 22,610 0.50 1.00 0.30 30.00 2.00 0.15
9-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 4,055 97 119 20,000 20,946 0.50 1.00 0.30 30.00 2.00 0.15
9-11 30# Linear Flush 25.0 10,562 10,699 255 255 1.00 30.00 2.00 0.15
9-12 Shut-In Shut-In -Interval 6Narwhal@ 17675.08 - 17678.94 ft 94.7 °FInterval 7Narwhal@ 17277.64 - 17281.5 ft 94.6 °FInterval 8Narwhal@ 16880.22 - 16884.08 ft 94.4 °FInterval 9Narwhal@ 16524.01 - 16527.87 ft 94.3 °FInterval 5Narwhal@ 18027.95 - 18031.81 ft 94.8 °FConoco Phillips - CD4-586 Actual Design 6
CUSTOMER Conoco Phillips API BFD (lb/gal)8.54 LAT 70.29234487
LEASE CD4-586 SALES ORDE BHST (°F)95 LONG -150.9872544
FORMATION Narwhal DATE Max Pressure (psi)7500 *Exceeds 80% of burst pressure*
Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)
50-103-20857
908818284
Liquid Additives Dry Additives
10-1 Shut-In Shut-In -
10-2 Seawater Prime Up Pressure Test 5.0 1,000 336 8 8 0.15
10-3 Shut-In Shut-In -
10-4 30# Linear Spacer and Ball Drop 15.0 1,260 1,362 32 32 1.00 30.00 1.50 0.15
10-5 30# Delta Frac Establish Stable Fluid 15.0 8,400 10,947 261 261 0.50 1.00 0.38 30.00 1.50 0.15
10-6 30# Delta Frac Pad 25.0 3,500 3,853 92 92 0.50 1.00 0.38 30.00 1.50 0.15
10-7 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,228 196 199 4,000 3,256 0.50 1.00 0.38 30.00 1.50 0.15
10-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,502 60 62 2,500 1,836 0.50 1.00 0.38 30.00 1.50 0.15
10-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,504 60 65 5,000 4,740 0.50 1.00 0.38 30.00 1.50 0.15
10-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,244 77 87 9,750 9,508 0.50 1.00 0.38 30.00 1.50 0.15
10-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,618 110 129 18,400 18,269 0.50 1.00 0.38 30.00 2.00 0.15
10-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,920 117 144 24,600 24,965 0.50 1.00 0.38 30.00 2.00 0.15
10-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,510 107 135 27,000 26,307 0.50 1.00 0.38 30.00 2.00 0.15
10-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,266 78 102 22,750 22,472 0.50 1.00 0.38 30.00 2.00 0.15
10-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,825 91 113 20,000 21,073 0.50 1.00 0.38 30.00 2.00 0.15
10-16 30# Delta Frac Spacer and Ball Drop 25.0 1,260 4,056 97 97 0.50 1.00 0.38 30.00 2.00 0.15
11-1 30# Delta Frac Establish Stable Fluid 15.0 8,400 22,505 536 536 0.50 1.00 0.30 30.00 1.50 0.15
11-2 30# Delta Frac Pad 25.0 3,500 3,387 81 81 0.50 1.00 0.30 30.00 1.50 0.15
11-3 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,812 210 214 4,000 3,421 0.50 1.00 0.30 30.00 1.50 0.15
11-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 3,075 73 76 2,500 2,532 0.50 1.00 0.30 30.00 1.50 0.15
11-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,536 60 65 5,000 4,509 0.50 1.00 0.30 30.00 1.50 0.15
11-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,399 81 91 9,750 9,679 0.50 1.00 0.30 30.00 1.50 0.15
11-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,591 109 128 18,400 17,914 0.50 1.00 0.30 30.00 2.00 0.15
11-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,902 117 143 24,600 24,400 0.50 1.00 0.30 30.00 2.00 0.15
11-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,489 107 135 27,000 26,469 0.50 1.00 0.30 30.00 2.00 0.15
11-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,329 79 104 22,750 23,628 0.50 1.00 0.30 30.00 2.00 0.15
11-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,885 93 115 20,000 21,259 0.50 1.00 0.30 30.00 2.00 0.15
11-12 30# Linear Spacer and Dart Drop 25.0 1,260 1,204 29 29 1.00 30.00 2.00 0.15
12-1 30# Linear Displace Dart to Seat 25.0 9,830 11,206 267 267 1.00 30.00 1.50
12-2 30# Delta Frac Establish Stable Fluid 15.0 8,400 5,348 127 127 0.50 1.00 0.30 30.00 1.50 0.15
12-3 30# Delta Frac Pad 25.0 3,500 3,679 88 88 0.50 1.00 0.30 30.00 1.50 0.15
12-4 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 9,062 216 219 4,000 3,072 0.50 1.00 0.30 30.00 1.50 0.15
12-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,502 60 62 2,500 1,976 0.50 1.00 0.30 30.00 1.50 0.15
12-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,506 60 65 5,000 4,994 0.50 1.00 0.30 30.00 1.50 0.15
12-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,263 78 88 9,750 9,718 0.50 1.00 0.30 30.00 1.50 0.15
12-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,652 111 130 18,400 18,280 0.50 1.00 0.30 30.00 2.00 0.15
12-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,927 117 144 24,600 24,937 0.50 1.00 0.30 30.00 2.00 0.15
12-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,484 107 136 27,000 27,347 0.50 1.00 0.30 30.00 2.00 0.15
12-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,260 78 102 22,750 22,888 0.50 1.00 0.30 30.00 2.00 0.15
12-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,546 84 105 20,000 19,261 0.50 1.00 0.30 30.00 2.00 0.15
12-13 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,806 43 43 0.50 1.00 0.30 30.00 2.00 0.15
13-1 30# Delta Frac Pad 25.0 3,500 3,680 88 88 0.50 1.00 0.30 30.00 1.50 0.15
13-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,638 206 209 4,000 3,025 0.50 1.00 0.30 30.00 1.50 0.15
13-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,501 60 62 2,500 2,299 0.50 1.00 0.30 30.00 1.50 0.15
13-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,499 60 65 5,000 4,780 0.50 1.00 0.30 30.00 1.50 0.15
13-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,240 77 87 9,750 9,250 0.50 1.00 0.30 30.00 1.50 0.15
13-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,611 110 129 18,400 18,187 0.50 1.00 0.30 30.00 2.00 0.15
13-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,932 117 144 24,600 24,862 0.50 1.00 0.30 30.00 2.00 0.15
13-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,482 107 136 27,000 27,216 0.50 1.00 0.30 30.00 2.00 0.15
13-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,255 78 102 22,750 23,006 0.50 1.00 0.30 30.00 2.00 0.15
13-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,316 79 99 20,000 18,994 0.50 1.00 0.30 30.00 2.00 0.15
13-11 30# Linear Spacer and Dart Drop 25.0 1,260 1,329 32 32 1.00 30.00 2.00 0.15
14-1 30# Delta Frac Pad 25.0 3,500 3,597 86 86 0.50 1.00 0.30 30.00 1.50 0.15
14-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,290 197 200 4,000 2,769 0.50 1.00 0.30 30.00 1.50 0.15
14-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,511 60 63 2,500 2,621 0.50 1.00 0.30 30.00 1.50 0.15
14-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,492 59 65 5,000 5,045 0.50 1.00 0.30 30.00 1.50 0.15
14-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,261 78 88 9,750 10,080 0.50 1.00 0.30 30.00 1.50 0.15
14-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,608 110 130 18,400 18,847 0.50 1.00 0.30 30.00 2.00 0.15
14-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,899 117 143 24,600 25,189 0.50 1.00 0.30 30.00 2.00 0.15
14-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,497 107 136 27,000 27,248 0.50 1.00 0.30 30.00 2.00 0.15
14-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,252 77 102 22,750 23,151 0.50 1.00 0.30 30.00 2.00 0.15
14-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,107 74 92 20,000 16,810 0.50 1.00 0.30 30.00 2.00 0.15
14-11 30# Linear Flush 25.0 9,326 9,456 225 225 1.00 30.00 2.00 0.15
14-12 Shut-In Shut-In -Interval 10Narwhal@ 16126.66 - 16130.52 ft 94.2 °FInterval 11Narwhal@ 15728.65 - 15732.51 ft 94.1 °FInterval 12Narwhal@ 15378.02 - 15381.88 ft 94 °FInterval 13Narwhal@ 14984.83 - 14988.335 ft 93.9 °FInterval 14Narwhal@ 14589.66 - 14593.165 ft 93.8 °FConoco Phillips - CD4-586 Actual Design 7
CUSTOMER Conoco Phillips API BFD (lb/gal)8.54 LAT 70.29234487
LEASE CD4-586 SALES ORDE BHST (°F)95 LONG -150.9872544
FORMATION Narwhal DATE Max Pressure (psi)7500 *Exceeds 80% of burst pressure*
Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)
50-103-20857
908818284
Liquid Additives Dry Additives
15-1 Shut-In Shut-In -
15-2 Seawater Prime Up Pressure Test 5.0 1,000 378 9 9 0.15
15-3 Shut-In Shut-In -
15-4 30# Linear Spacer and Dart Drop 15.0 1,260 1,484 35 35 1.00 30.00 1.50 0.15
15-5 30# Delta Frac Establish Stable Fluid 15.0 8,400 4,383 104 104 0.50 1.00 0.30 30.00 1.50 0.15
15-6 30# Delta Frac Pad 25.0 3,500 3,354 80 80 0.50 1.00 0.30 30.00 1.50 0.15
15-7 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 10,031 239 242 4,000 2,569 0.50 1.00 0.30 30.00 1.50 0.15
15-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,503 60 61 2,500 1,378 0.50 1.00 0.30 30.00 1.50 0.15
15-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,504 60 64 5,000 4,510 0.50 1.00 0.30 30.00 1.50 0.15
15-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,372 80 90 9,750 9,152 0.50 1.00 0.30 30.00 1.50 0.15
15-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,604 110 129 18,400 18,088 0.50 1.00 0.30 30.00 2.00 0.15
15-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,925 117 144 24,600 24,744 0.50 1.00 0.30 30.00 2.00 0.15
15-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,504 107 136 27,000 27,235 0.50 1.00 0.30 30.00 2.00 0.15
15-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,250 77 101 22,750 22,680 0.50 1.00 0.30 30.00 2.00 0.15
15-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,371 80 100 20,000 18,208 0.50 1.00 0.30 30.00 2.00 0.15
15-16 30# Delta Frac Spacer and Dart Drop 25.0 1,260 1,888 45 45 0.50 1.00 0.30 30.00 2.00 0.15
16-1 30# Delta Frac Pad 25.0 3,500 3,669 87 87 0.50 1.00 0.30 30.00 1.50 0.15
16-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 13,490 321 327 4,000 5,214 0.50 1.00 0.30 30.00 1.50 0.15
16-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,514 60 62 2,500 2,172 0.50 1.00 0.30 30.00 1.50 0.15
16-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,501 60 65 5,000 4,806 0.50 1.00 0.30 30.00 1.50 0.15
16-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,261 78 88 9,750 9,622 0.50 1.00 0.30 30.00 1.50 0.15
16-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 4,603 110 131 18,400 20,071 0.50 1.00 0.30 30.00 2.00 0.15
16-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 4,919 117 143 24,600 24,224 0.50 1.00 0.30 30.00 2.00 0.15
16-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 4,503 107 136 27,000 27,136 0.50 1.00 0.30 30.00 2.00 0.15
16-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 3,232 77 101 22,750 22,857 0.50 1.00 0.30 30.00 2.00 0.15
16-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 3,034 72 89 20,000 15,755 0.50 1.00 0.30 30.00 2.00 0.15
16-11 30# Delta Frac Spacer and Dart Drop 15.0 1,260 1,826 43 43 0.50 1.00 0.30 30.00 2.00 0.15
17-1 30# Delta Frac Pad 25.0 3,500 3,784 90 90 0.50 1.00 0.30 30.00 1.50 0.15
17-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 15,232 363 371 4,000 7,499 0.50 1.00 0.30 30.00 1.50 0.15
17-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 2,500 2,950 70 73 2,500 2,937 0.50 1.00 0.30 30.00 1.50 0.15
17-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 2,500 2,525 60 66 5,000 5,084 0.50 1.00 0.30 30.00 1.50 0.15
17-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 3,250 3,290 78 89 9,750 10,155 0.50 1.00 0.30 30.00 1.50 0.15
17-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 4,600 3,970 95 112 18,400 16,098 0.50 1.00 0.30 30.00 2.00 0.15
17-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,920 2,229 53 65 24,600 11,140 0.50 1.00 0.30 30.00 2.00 0.15
17-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 1,897 45 57 27,000 10,948 0.50 1.00 0.30 30.00 2.00 0.15
17-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,250 1,706 41 53 22,750 11,794 0.50 1.00 0.30 30.00 2.00 0.15
17-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 2,394 57 65 20,000 7,973 0.50 1.00 0.30 30.00 2.00 0.15
17-11 30# Linear Flush 25.0 8,678 8,490 202 202 1.00 30.00 2.00 0.15
17-12 Shut-In Shut-In -
909,315 959,963 22,856 25,216 2,279,000 2,220,836
Design 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-6
816,020 866,880 2,210,000 2,155,982 2,220,900 (gal) (gal) (gal) (lbs) (lbs)(lbs)
114,263 91,739 68,000 64,854 75,000 Initial Design Material Volume 408.0 930.3 244.8 27,908.5 1,590.8 138.1
4,000 1,344 - - - Actual Design Material Volume 433.4 958.6 263.9 28,758.6 1,644.9 141.8
- - - Physical Material Volume Pumped 430 950 270 27193 1,667 141
- - - - - Physical Material Volume Deviance -1% -1% 2% -5% 1% -1%
- -** IFS numbers for proppant are taken from software calculations based on multiple variables MicroMotion Volume Pumped 432 953 272 28,034 1,418 -
- -** Proppant is billed from Weight Ticket volumes MicroMotion Volume Deviance 0% -1% 3% -3% -14% -
- -Interval 15Narwhal@ 14238.88 - 14242.385 ft 93.7 °F-
Fluid Type
30# Delta Frac
30# Linear
Seawater
Freeze Protect
-
Proppant Type
Wanli 20/40 Ceramic
100M
-
-
-
-
-Interval 17Narwhal@ 13576.36 - 13579.865 ft 93.4 °FInterval 16Narwhal@ 13928.77 - 13932.275 ft 93.7 °FConoco Phillips - CD4-586 Actual Design 8
9/3/23 7:54
9/3/23 11:39
225 min
12.7 bpm
4,779 psi
5,854 psi
3 bbl
25.4 bpm
3,948 psi
4,166 psi
23.7 bpm
3,347 psi
3,315 psi
3,809 psi
1,947 hhp
600 psi
501 psi
617 psi
6.35 ppg
5
5
35.0 %
35.5 %
24 cP
83.3 F
8.5
Minifrac
21.1 bpm
2492 psi
3483 psi
25.66 bpm
3606 psi
3736 psi
132,665 lbs
4,604 lbs
137,269 lbs
137,269 lbs
0 lbs
76,412 gal 1,819 bbls
33,167 gal 790 bbls
294 gal 7 bbls
0 gal 0 bbls
Wanli 20/40 Ceramic Pumped:
Proppant Summary
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
CD4-586 - Narwhal - 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
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:
Freeze Protect Volume:
Diagnostic method
Pump Time:
Pad Percentage Actual
Proppant left in Wellbore:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pumps Ending Stage:
Max Proppant Concentration:
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Minifrac Max Rate:
Average Missile HHP:
Conoco Phillips - CD4-586 Interval Summary 9
12,701 gal 302 bbls
10,180 gal 242 bbls
49,315 gal 1,174 bbls
3,038 gal 72 bbls
4,010 gal 95 bbls
2,375 gal 57 bbls
6,397 gal 152 bbls
6,635 gal 158 bbls
12,653 gal 301 bbls
2,121 gal 51 bbls
154 gal 4 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Wellhead opened to burst Arsenal sleeve at 600psi. Arsenal Sleeve Shifted at 7557psi on
surface. Performed step rate test per CoP onsite instructions. Built crosslink at 15bpm prior to
starting minifrac. Adjusted MO-67 as needed. Pumped additional 100M after results of
minifrac. Pulled proppant screen from top of blender going into 3ppg due to screens packing
off with wet proppant. After the ball drop pump 458 lost rate. Rate was moved around
returning full rate to 458. Interval pumped to design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Minifrac - Flush Volume:
DFIT Volume:
Arsenal Sleeve Shift Volume:
Step Rate Test Volume:
Spacer and Ball Drop Volume:
Interval Status:
Nathan Brzezinski
Daniel Faur
Baskoro Tejo
Chad Burkett
Keegan Lambe
Minifrac - Treatment Volume:
Fluid Summary (by stage description)
Displace Ball to Seat Volume:
Pad Volume:
Establish Stable Fluid Volume:
Minifrac - Establish Fluid Volume:
Proppant Laden Fluid Volume:
Conoco Phillips - CD4-586 Interval Summary 10
9/3/23 11:39
9/3/23 12:42
63 min
12.0 bpm
6,243 psi
6,910 psi
-4 bbl
25.5 bpm
3,600 psi
3,770 psi
24.1 bpm
3,310 psi
3,287 psi
3,647 psi
1,954 hhp
599 psi
623 psi
6.33 ppg
5
5
31.0 %
32.1 %
23 cP
83.5 F
8.5
130,903 lbs
3,989 lbs
134,892 lbs
134,892 lbs
0 lbs
57,258 gal 1,363 bbls
9,835 gal 234 bbls
46,091 gal 1,097 bbls
1,332 gal 32 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Baskoro Tejo
Keegan Lambe
Nathan Brzezinski
Daniel Faur
*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.Chad Burkett
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
30# Delta Frac Volume:
Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Proppant left in Wellbore:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Interval Status:
While pumping ball down for interval 02, hose on 458 was noticed to potentially be going bad.
Pump was shut in and backup pump opened. Ball seat observed, returned to 4000lb design of
100M. Started 100M on schedule. Screens could not be put back in with the wet 20/40.
Interval pumped to design.
Proppant Summary
Proppant in Formation:
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:
CD4-586 - Narwhal - 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:
Pad Percentage Design
Pad Percentage Actual
Conoco Phillips - CD4-586 Interval Summary 11
6,243
9/3/23 12:42
9/3/23 13:46
64 min
11.8 bpm
6,020 psi
6,420 psi
-6 bbl
25.6 bpm
3,552 psi
3,795 psi
24.0 bpm
2,929 psi
2,911 psi
3,486 psi
1,720 hhp
607 psi
627 psi
6.90 ppg
5
5
31 %
33.9 %
26 cP
84.9 F
8.5
131,919 lbs
4,535 lbs
136,454 lbs
136,454 lbs
59,454 gal 1,416 bbls
10,318 gal 246 bbls
47,842 gal 1,139 bbls
1,294 gal 31 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Proppant Summary
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Interval Status:
Ball seat observed. Pump kicked out due to preload adjustment during 1ppg proppant. Interval
pumped to design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Baskoro Tejo
Chad Burkett
Keegan Lambe
Nathan Brzezinski
Daniel Faur
Average BH Pressure:
Average Visc:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
Max Proppant Concentration:
Pumps Starting Stage:
Pad Percentage Actual
Proppant Laden Fluid Volume:
Start Date/Time:
Max Surface Pressure:
Max BH Pressure:
Pump Time:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
End Date/Time:
Initial Rate (Breakdown):
CD4-586 - Narwhal - Interval 3
Initial OA Pressure:
Max OA Pressure:
Average Missile HHP:
Pumps Ending Stage:
Pad Percentage Design
30# Delta Frac Volume:
Total Proppant Pumped* :
Pad Volume:
Spacer and Ball Drop Volume:
Average Temp:
Average pH:
100M Pumped:
Wanli 20/40 Ceramic Pumped:
Conoco Phillips - CD4-586 Interval Summary 12
9/3/23 13:46
9/3/23 14:40
54 min
12.7 bpm
5,457 psi
6,395 psi
0 bbl
25.6 bpm
3,190 psi
3,596 psi
24.5 bpm
2,773 psi
2,754 psi
3,361 psi
1,666 hhp
606 psi
627 psi
8.59 ppg
5
5
31.3 %
30.5 %
23 cP
84.8 F
8.5
2714 psi
0.621 psi/ft
2639 psi
2626 psi
2617 psi
134,282 lbs
3,735 lbs
138,017 lbs
137,557 lbs
48,248 gal 1,149 bbls
11,941 gal 284 bbls
7,492 gal 178 bbls
40,756 gal 970 bbls
11,941 gal 284 bbls
Interval Summary
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Pad Volume:
100M Pumped:
Pumps Starting Stage:
Average Rate:
Max OA Pressure:
Average Temp:
Average pH:
Max BH Pressure:
Average Missile Pressure:
Average Surface Pressure:
Max Proppant Concentration:
Pumps Ending Stage:
Pad Percentage Design
Final Fracture Gradient:
Final 5 min:
30# Delta Frac Volume:
30# Linear Volume:
CD4-586 - Narwhal - Interval 4
ISDP:
Wanli 20/40 Ceramic Pumped:
Initial OA Pressure:
Final 15 min:
Max Surface Pressure:
Dart/Ball Early :
Initial Rate (Breakdown):
Start Date/Time:
Average BH Pressure:
Average Missile HHP:
Pad Percentage Actual
Final 10 min:
Max Rate:
End Date/Time:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Average Visc:
Pump Time:
Proppant Laden Fluid Volume:
Flush Volume:
Conoco Phillips - CD4-586 Interval Summary 13
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Ball seat observed. During the 7ppg stage the proppant was noted to be dry going into the
hopper. Sand concentration jumped up to 8.5ppg when staging to 7ppg. Significant
adjustments where made to the screws to bring concentration back to 7ppg. Interval pumped
to design. Daniel Faur
Keegan Lambe
Nathan Brzezinski
*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.
Baskoro Tejo
Chad Burkett
Conoco Phillips - CD4-586 Interval Summary 14
9/4/23 7:08
9/4/23 8:33
85 min
12.0 bpm
5,886 psi
6,396 psi
1 bbl
25.6 bpm
3,124 psi
3,665 psi
24.0 bpm
2,914 psi
2,896 psi
3,484 psi
1,711 hhp
627 psi
447 psi
558 psi
7.13 ppg
5
5
31 %
33.3 %
24 cP
86.4 F
8.4
130,656 lbs
4,288 lbs
134,944 lbs
134,944 lbs
56,639 gal 1,349 bbls
1,401 gal 33 bbls
336 gal 8 bbls
8,326 gal 198 bbls
42,006 gal 1,000 bbls
2,705 gal 64 bbls
5,003 gal 119 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Proppant Summary
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Start Date/Time:
Dart/Ball Early :
Max BH Pressure:
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Seawater Volume:
Average pH:
Average Rate:
Average BH Pressure:
Open Well Pressure:
Max Proppant Concentration:
Max Rate:
30# Delta Frac Volume:
Daniel Faur
*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.
Baskoro Tejo
Chad Burkett
CD4-586 - Narwhal - Interval 5
Nathan Brzezinski
Average Missile Pressure:
Average Surface Pressure:
Initial BH Pressure (Breakdown):
Keegan Lambe
Initial OA Pressure:
Max OA Pressure:
Interval Status:
Wellhead opened at 07:08. Established injection ahead of dropping the dart. Hose on pump
621 had a leak. Shut in pump and opened 245 in place. Interval pumped to design.
Average Visc:
30# Linear Volume:
Pumps Starting Stage:
Average Temp:
Establish Stable Fluid Volume:
Pump Time:
Initial Surface Pressure (Breakdown):
Spacer and Ball Drop Volume:
Proppant in Formation:
Pad Volume:
Max Surface Pressure:
Average Missile HHP:
Initial Rate (Breakdown):
Pad Percentage Design
Pad Percentage Actual
End Date/Time:
Proppant Laden Fluid Volume:
Pumps Ending Stage:
Conoco Phillips - CD4-586 Interval Summary 15
9/4/23 8:33
9/4/23 9:30
57 min
12.1 bpm
5,804 psi
6,610 psi
-3 bbl
25.5 bpm
3,141 psi
3,625 psi
23.6 bpm
2,719 psi
2,705 psi
3,366 psi
1,575 hhp
558 psi
599 psi
7.18 ppg
5
5
31.3 %
35.0 %
24 cP
86 F
8.4
127,117 lbs
4,282 lbs
131,399 lbs
131,399 lbs
51,306 gal 1,222 bbls
0 gal 0 bbls
7,914 gal 188 bbls
42,043 gal 1,001 bbls
1,349 gal 32 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Nathan Brzezinski
Daniel Faur
*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.Baskoro Tejo
Chad Burkett
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Start Date/Time:
Average Rate:
Initial Rate (Breakdown):
Max Rate:
Dart/Ball Early :
Average Missile Pressure:
Average Surface Pressure:
30# Delta Frac Volume:
30# Linear Volume:
Pumps Ending Stage:
Average pH:
Pumps Starting Stage:
Max Surface Pressure:
Spacer and Ball Drop Volume:
Pad Percentage Design
Average Temp:
Pad Percentage Actual
CD4-586 - Narwhal - Interval 6
Interval Status:
Interval pumped to design.
Max OA Pressure:
Wanli 20/40 Ceramic Pumped:
End Date/Time:
Pump Time:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Average BH Pressure:
100M Pumped:
Max Proppant Concentration:
Total Proppant Pumped* :
Proppant in Formation:
Pad Volume:
Proppant Laden Fluid Volume:
Average Missile HHP:
Average Visc:
Initial OA Pressure:
Conoco Phillips - CD4-586 Interval Summary 16
9/4/23 9:30
9/4/23 10:20
50 min
11.9 bpm
5,519 psi
6,402 psi
0 bbl
25.5 bpm
3,331 psi
3,581 psi
23.4 bpm
2,755 psi
2,744 psi
3,387 psi
1,581 hhp
588 psi
612 psi
8.41 ppg
5
5
25.7 %
25.6 %
22 cP
87 F
8.4
131,542 lbs
2,604 lbs
134,146 lbs
134,146 lbs
42,850 gal 1,020 bbls
0 gal 0 bbls
3,468 gal 83 bbls
38,107 gal 907 bbls
1,275 gal 30 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
CD4-586 - Narwhal - Interval 7
Interval Summary
Average BH Pressure:
Max BH Pressure:
Max Surface Pressure:
Max Rate:
Initial OA Pressure:
Average Missile HHP:
Pad Percentage Actual
Pad Volume:
Proppant Summary
Fluid Summary (by fluid description)
Keegan Lambe
Nathan Brzezinski
Daniel Faur
*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.
Baskoro Tejo
Chad Burkett
Pumps Ending Stage:
Fluid Summary (by stage description)
Average Visc:
Average Temp:
Max OA Pressure:
Average Missile Pressure:
Average Rate:
Max Proppant Concentration:
Pumps Starting Stage:
End Date/Time:
Pump Time:
Average pH:
Average Surface Pressure:
Proppant Laden Fluid Volume:
Wanli 20/40 Ceramic Pumped:
100M Pumped:
30# Linear Volume:
Total Proppant Pumped* :
Spacer and Ball Drop Volume:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Start Date/Time:
Proppant in Formation:
Interval Status:
Interval pumped to design.
Pad Percentage Design
30# Delta Frac Volume:
Conoco Phillips - CD4-586 Interval Summary 17
9/4/23 10:20
9/4/23 11:11
51 min
12.4 bpm
5,695 psi
6,272 psi
-1 bbl
25.6 bpm
2,974 psi
3,389 psi
23.5 bpm
2,649 psi
2,640 psi
3,270 psi
1,525 hhp
599 psi
614 psi
8.36 ppg
5
5
25.7 %
26.9 %
23 cP
85.6 F
8.4
131,898 lbs
3,899 lbs
135,797 lbs
135,797 lbs
44,449 gal 1,058 bbls
0 gal 0 bbls
3,426 gal 82 bbls
39,618 gal 943 bbls
1,405 gal 33 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Chad Burkett
Interval Summary
Average BH Pressure:
Wanli 20/40 Ceramic Pumped:
30# Delta Frac Volume:
Initial Surface Pressure (Breakdown):
Average Surface Pressure:
Max Rate:
Average Visc:
Average Temp:
Initial OA Pressure:
CD4-586 - Narwhal - Interval 8
Interval Status:
Interval pumped to design. Keegan Lambe
Nathan Brzezinski
Daniel Faur
*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.Baskoro Tejo
Proppant Summary
100M Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Proppant in Formation:
Average Missile Pressure:
Average Missile HHP:
Pad Percentage Design
Max OA Pressure:
Pumps Starting Stage:
Initial Rate (Breakdown):
End Date/Time:
Max BH Pressure:
Average Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Pad Percentage Actual
Proppant Laden Fluid Volume:
Max Surface Pressure:
30# Linear Volume:
Pump Time:
Pad Volume:
Max Proppant Concentration:
Dart/Ball Early :
Pumps Ending Stage:
Average pH:
Total Proppant Pumped* :
Spacer and Ball Drop Volume:
Conoco Phillips - CD4-586 Interval Summary 18
9/4/23 11:11
9/4/23 11:58
47 min
11.9 bpm
5,404 psi
5,668 psi
-3 bbl
25.4 bpm
2,814 psi
3,441 psi
24.5 bpm
2,486 psi
2,472 psi
3,272 psi
1,493 hhp
601 psi
614 psi
8.39 ppg
5
5
25.7 %
24.8 %
23 cP
86.3 F
8.4
2658 psi
0.620 psi/ft
2626 psi
2579 psi
2533 psi
129,687 lbs
2,093 lbs
131,780 lbs
131,706 lbs
41,960 gal 999 bbls
10,699 gal 255 bbls
4,302 gal 102 bbls
37,658 gal 897 bbls
10,699 gal 255 bbls
Completed
CD4-586 - Narwhal - Interval 9
Interval Summary
Max Surface Pressure:
Final 5 min:
Total Proppant Pumped* :
Initial Rate (Breakdown):
Final 10 min:
End Date/Time:
Initial Surface Pressure (Breakdown):
Average BH Pressure:
Max Rate:
Max BH Pressure:
Pump Time:
Dart/Ball Early :
Initial OA Pressure:
Max OA Pressure:
Pad Percentage Design
Pad Percentage Actual
Interval Status:
Proppant in Formation:
Proppant Laden Fluid Volume:
Proppant Summary
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Fluid Summary (by fluid description)
Average Visc:
Average Temp:
Pumps Ending Stage:
Average Missile Pressure:
Average Surface Pressure:
Initial BH Pressure (Breakdown):
30# Delta Frac Volume:
30# Linear Volume:
Pad Volume:
Max Proppant Concentration:
Pumps Starting Stage:
Average Missile HHP:
Flush Volume:
ISDP:
Final Fracture Gradient:
Average Rate:
Fluid Summary (by stage description)
Average pH:
Final 15 min:
Start Date/Time:
Conoco Phillips - CD4-586 Interval Summary 19
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Nathan Brzezinski
Daniel Faur
*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.Baskoro Tejo
Held pad slightly longer to get proppant started. 100M all in hopper to start. Switched to a wet
bin during 6ppg, adjusted screws to compensate, staged off volume. Interval pumped to
design.
Chad Burkett
Conoco Phillips - CD4-586 Interval Summary 20
9/5/23 6:59
9/5/23 8:26
87 min
12.2 bpm
4,767 psi
6,159 psi
2 bbl
25.5 bpm
2,642 psi
3,295 psi
24.2 bpm
2,296 psi
2,282 psi
3,142 psi
1,360 hhp
371 psi
409 psi
529 psi
8.35 ppg
5
5
25.8 %
25.8 %
23 cP
86.7 F
8.3
129,170 lbs
3,256 lbs
132,426 lbs
132,426 lbs
56,473 gal 1,345 bbls
1,362 gal 32 bbls
336 gal 8 bbls
0 gal 0 bbls
3,853 gal 92 bbls
37,617 gal 896 bbls
5,418 gal 129 bbls
10,947 gal 261 bbls
Completed
Fluid Summary (by fluid description)
Proppant in Formation:
Average Temp:
Average pH:
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Pad Percentage Actual
Average Missile HHP:
Average Missile Pressure:
Max Proppant Concentration:
100M Pumped:
Interval Summary
Proppant Summary
Wanli 20/40 Ceramic Pumped:
Establish Stable Fluid Volume:
Interval Status:
Pumps Ending Stage:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Max OA Pressure:
End Date/Time:
Pump Time:
Average Surface Pressure:
Average BH Pressure:
CD4-586 - Narwhal - Interval 10
30# Linear Volume:
Seawater Volume:
Max BH Pressure:
Freeze Protect Volume:
Pad Volume:
Average Visc:
Fluid Summary (by stage description)
Start Date/Time:
Initial Surface Pressure (Breakdown):
Spacer and Ball Drop Volume:
Average Rate:
Pad Percentage Design
Initial Rate (Breakdown):
Pumps Starting Stage:
Open Well Pressure:
Total Proppant Pumped* :
Proppant Laden Fluid Volume:
30# Delta Frac Volume:
Conoco Phillips - CD4-586 Interval Summary 21
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Chad Burkett
Ball seat observed. Adjusted MO-67 conc based off of the daily dilution and live results. Held
pad long while troubleshooting suction issues with the Blender. During 8ppg crosslink samples
started to come in weak. Held the spacer behind the ball longer to allow to maintain rate while
displacing 8ppg, slowed to 15bpm once volume of 8ppg had been displaced while waiting for
ball.
Keegan Lambe
Nathan Brzezinski
David Martinez
*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.Baskoro Tejo
Conoco Phillips - CD4-586 Interval Summary 22
9/5/23 8:26
9/5/23 11:27
181 min
12.2 bpm
4,666 psi
6,108 psi
13 bbl
25.6 bpm
2,860 psi
3,345 psi
22.1 bpm
2,333 psi
2,327 psi
3,165 psi
1,263 hhp
559 psi
592 psi
8.37 ppg
5
5
25.8 %
25.5 %
23 cP
86.6 F
8.4
130,390 lbs
3,421 lbs
133,811 lbs
133,741 lbs
64,910 gal 1,545 bbls
1,204 gal 29 bbls
3,387 gal 81 bbls
39,018 gal 929 bbls
1,204 gal 29 bbls
22,505 gal 536 bbls
Completed
CD4-586 - Narwhal - Interval 11
Interval Summary
Fluid Summary (by fluid description)
30# Delta Frac Volume:
30# Linear Volume:
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
Initial BH Pressure (Breakdown):
Average Temp:
Pumps Starting Stage:
Initial OA Pressure:
Pumps Ending Stage:
Max Surface Pressure:
Interval Status:
Average Visc:
End Date/Time:
Pump Time:
Initial Surface Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max BH Pressure:
Average Rate:
Average Surface Pressure:
Proppant Laden Fluid Volume:
Initial Rate (Breakdown):
Proppant in Formation:
Total Proppant Pumped* :
100M Pumped:
Pad Percentage Design
Average pH:
Max Proppant Concentration:
Average BH Pressure:
Average Missile Pressure:
Max OA Pressure:
Pad Percentage Actual
Start Date/Time:
Proppant Summary
Pad Volume:
Spacer and Dart Drop Volume:
Wanli 20/40 Ceramic Pumped:
Average Missile HHP:
Conoco Phillips - CD4-586 Interval Summary 23
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Nathan Brzezinski
David Martinez
*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.Baskoro Tejo
Chad Burkett
After ball seated crosslink could not be reestablished. Checked chemicals on location,
crosslinked ADP tub and tanks 17-11 to check crosslink along with tanks not refilled. Tanks
16/17 showed weak to no crosslink when tested on their own. ADP tub with old stock
chemicals showed weak to no crosslink, ADP tub with new materials showed weak to no
Conoco Phillips - CD4-586 Interval Summary 24
9/5/23 11:27
9/5/23 12:40
73 min
18.5 bpm
1,940 psi
3,079 psi
11 bbl
27.5 bpm
3,309 psi
3,527 psi
23.3 bpm
2,326 psi
2,315 psi
3,015 psi
1,329 hhp
561 psi
591 psi
7.99 ppg
5
3
25.8 %
27.0 %
23 cP
87 F
8.4
129,401 lbs
3,072 lbs
132,473 lbs
132,473 lbs
49,035 gal 1,168 bbls
11,206 gal 267 bbls
11,206 gal 267 bbls
3,679 gal 88 bbls
38,202 gal 910 bbls
1,806 gal 43 bbls
5,348 gal 127 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Dart seat observed, shut down for a water hammer analysis. During 4 to 5 ppg pumps started
to cavitate. Closed in pumps and switched to back up pumps. Interval pumped to design.
Keegan Lambe
Nathan Brzezinski
David Martinez
*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.Baskoro Tejo
Chad Burkett
Interval Status:
CD4-586 - Narwhal - Interval 12
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
30# Delta Frac Volume:
Fluid Summary (by stage description)
Max BH Pressure:
Max Surface Pressure:
Spacer and Dart Drop Volume:
30# Linear Volume:
Pumps Ending Stage:
Initial OA Pressure:
End Date/Time:
Pump Time:
Average pH:
Average Surface Pressure:
Average BH Pressure:
Average Missile HHP:
Initial Rate (Breakdown):
Pad Percentage Design
Max Proppant Concentration:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Start Date/Time:
Pumps Starting Stage:
Max Rate:
Initial Surface Pressure (Breakdown):
Average Temp:
Average Rate:
Wanli 20/40 Ceramic Pumped:
Total Proppant Pumped* :
Establish Stable Fluid Volume:
Pad Percentage Actual
Average Missile Pressure:
Max OA Pressure:
100M Pumped:
Proppant in Formation:
Pad Volume:
Proppant Laden Fluid Volume:
Displace Dart to Seat Volume:
Average Visc:
Conoco Phillips - CD4-586 Interval Summary 25
9/5/23 12:40
9/5/23 13:29
49 min
12.2 bpm
2,666 psi
3,191 psi
3 bbl
26.4 bpm
3,172 psi
3,465 psi
23.3 bpm
2,446 psi
2,434 psi
3,032 psi
1,395 hhp
573 psi
591 psi
8.52 ppg
5
4
25.8 %
26.5 %
23 cP
86.9 F
8.5
128,594 lbs
3,025 lbs
131,619 lbs
131,619 lbs
41,154 gal 980 bbls
1,329 gal 32 bbls
0 gal 0 bbls
0 gal 0 bbls
3,680 gal 88 bbls
37,474 gal 892 bbls
1,329 gal 32 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
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.Baskoro Tejo
Chad Burkett
CD4-586 - Narwhal - Interval 13
Interval Summary
Proppant Summary
Fluid Summary (by stage description)
Pumped dart down in crosslink. Dart seat observed. Pumps cavitated during 7ppg. Interval
pumped to design.
Keegan Lambe
Nathan Brzezinski
David Martinez
Fluid Summary (by fluid description)
Seawater Volume:
Spacer and Dart Drop Volume:
Average Rate:
Dart/Ball Early :
Max OA Pressure:
Initial BH Pressure (Breakdown):
Max Rate:
Start Date/Time:
End Date/Time:
Average BH Pressure:
Average Missile HHP:
Freeze Protect Volume:
Average Missile Pressure:
Average Surface Pressure:
Pad Percentage Design
Pad Percentage Actual
Total Proppant Pumped* :
30# Linear Volume:
Pumps Ending Stage:
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Average pH:
Max Surface Pressure:
Pump Time:
Max Proppant Concentration:
Pumps Starting Stage:
Initial OA Pressure:
100M Pumped:
Pad Volume:
Proppant Laden Fluid Volume:
Proppant in Formation:
Wanli 20/40 Ceramic Pumped:
30# Delta Frac Volume:
Conoco Phillips - CD4-586 Interval Summary 26
9/5/23 13:29
9/5/23 14:17
48 min
11.1 bpm
2,153 psi
2,818 psi
5 bbl
27.0 bpm
3,223 psi
3,191 psi
23.4 bpm
2,386 psi
2,378 psi
2,930 psi
1,371 hhp
581 psi
589 psi
8.43 ppg
4
4
25.8 %
25.9 %
22 cP
86.7 F
8.5
2669 psi
0.632 psi/ft
2614 psi
2586 psi
2565 psi
128,991 lbs
2,769 lbs
131,760 lbs
131,760 lbs
40,514 gal 965 bbls
9,456 gal 225 bbls
3,597 gal 86 bbls
36,917 gal 879 bbls
9,456 gal 225 bbls
Completed
Average Visc:
Average Temp:
Pumps Starting Stage:
Pumps Ending Stage:
Average pH:
Average Missile HHP:
Average BH Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Initial Rate (Breakdown):
Max BH Pressure:
Average Rate:
Average Surface Pressure:
Average Missile Pressure:
Final Fracture Gradient:
Pad Percentage Design
ISDP:
Pad Percentage Actual
Final 15 min:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
30# Linear Volume:
Proppant Laden Fluid Volume:
CD4-586 - Narwhal - Interval 14
Interval Summary
Flush Volume:
Total Proppant Pumped* :
30# Delta Frac Volume:
Interval Status:
Final 5 min:
Proppant in Formation:
Pad Volume:
100M Pumped:
Final 10 min:
Wanli 20/40 Ceramic Pumped:
Initial OA Pressure:
Pump Time:
End Date/Time:
Max OA Pressure:
Max Proppant Concentration:
Max Surface Pressure:
Max Rate:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Conoco Phillips - CD4-586 Interval Summary 27
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pumped dart down in crosslink. Muted dart seat. Interval pumped to design. Keegan Lambe
Nathan Brzezinski
David Martinez
*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.Baskoro Tejo
Chad Burkett
Conoco Phillips - CD4-586 Interval Summary 28
9/6/23 6:58
9/6/23 8:10
72 min
12.0 bpm
2,609 psi
3,341 psi
6 bbl
27.7 bpm
2,873 psi
3,143 psi
23.9 bpm
2,344 psi
2,335 psi
2,987 psi
1,374 hhp
311 psi
392 psi
527 psi
8.27 ppg
5
5
25.7 %
28.0 %
23 cP
87.5 F
8.4
125,995 lbs
2,569 lbs
128,564 lbs
128,564 lbs
48,689 gal 1,159 bbls
1,484 gal 35 bbls
378 gal 9 bbls
3,354 gal 80 bbls
39,064 gal 930 bbls
3,372 gal 80 bbls
4,383 gal 104 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Nathan Brzezinski
David Martinez
*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.
Baskoro Tejo
Chad Burkett
Proppant Summary
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
30# Delta Frac Volume:
Pad Volume:
Wanli 20/40 Ceramic Pumped:
100M Pumped:
CD4-586 - Narwhal - Interval 15
Total Proppant Pumped* :
Interval Summary
Max OA Pressure:
Max BH Pressure:
Max Rate:
Max Surface Pressure:
Average Rate:
Initial OA Pressure:
Average BH Pressure:
Open Well Pressure:
End Date/Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Surface Pressure:
Start Date/Time:
Average Temp:
Average Visc:
Average pH:
Max Proppant Concentration:
Dart Seat observed. Interval pumped to design.
Pump Time:
Pad Percentage Actual
Average Missile Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Pad Percentage Design
Average Missile HHP:
Seawater Volume:
30# Linear Volume:
Establish Stable Fluid Volume:
Proppant Laden Fluid Volume:
Spacer and Dart Drop Volume:
Interval Status:
Conoco Phillips - CD4-586 Interval Summary 29
9/6/23 8:10
9/6/23 9:04
54 min
11.9 bpm
3,804 psi
4,196 psi
3 bbl
25.7 bpm
2,638 psi
2,981 psi
23.7 bpm
2,233 psi
2,229 psi
2,880 psi
1,297 hhp
527 psi
560 psi
8.30 ppg
5
5
25.7 %
33.7 %
23 cP
84.3 F
8.5
126,643 lbs
5,214 lbs
131,857 lbs
131,857 lbs
47,552 gal 1,132 bbls
0 gal 0 bbls
3,669 gal 87 bbls
42,057 gal 1,001 bbls
1,826 gal 43 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Dart Seat observed. Interval pumped to design. Keegan Lambe
Nathan Brzezinski
David Martinez
*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.
Baskoro Tejo
Chad Burkett
CD4-586 - Narwhal - Interval 16
Pad Volume:
Proppant Laden Fluid Volume:
Pumps Ending Stage:
Average Missile HHP:
Interval Summary
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Pad Percentage Actual
Initial OA Pressure:
Max Surface Pressure:
Pad Percentage Design
Max Proppant Concentration:
Average Visc:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Interval Status:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Average Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
30# Delta Frac Volume:
Dart/Ball Early :
Spacer and Dart Drop Volume:
Max OA Pressure:
30# Linear Volume:
Average Temp:
Initial BH Pressure (Breakdown):
Start Date/Time:
End Date/Time:
100M Pumped:
Wanli 20/40 Ceramic Pumped:
Pump Time:
Average pH:
Fluid Summary (by stage description)
Conoco Phillips - CD4-586 Interval Summary 30
9/6/23 9:04
9/6/23 9:49
45 min
12.7 bpm
2,230 psi
2,889 psi
0 bbl
25.6 bpm
2,634 psi
2,927 psi
23.3 bpm
2,217 psi
2,209 psi
2,862 psi
1,263 hhp
560 psi
577 psi
7.96 ppg
5
5
25.7 %
44.4 %
23 cP
84.3 F
8.5
0:00 psi
0.641 psi/ft
2622 psi
2592 psi
2581 psi
76,129 lbs
7,499 lbs
83,628 lbs
83,628 lbs
57 lbs
39,977 gal 952 bbls
8,490 gal 202 bbls
0 gal 0 bbls
0 gal 0 bbls
3,784 gal 90 bbls
36,193 gal 862 bbls
8,490 gal 202 bbls
Cut Short
Interval Summary
Final Fracture Gradient:
Final 5 min:
Proppant Summary
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
CD4-586 - Narwhal - Interval 17
Wanli 20/40 Ceramic Pumped:
30# Delta Frac Volume:
Seawater Volume:
Freeze Protect Volume:
Proppant left in Wellbore:
30# Linear Volume:
Final 15 min:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pad Volume:
Proppant Laden Fluid Volume:
Proppant in Formation:
Average BH Pressure:
Average Missile HHP:
Pad Percentage Actual
Average pH:
Average Surface Pressure:
Pump Time:
Start Date/Time:
100M Pumped:
Average Visc:
Pad Percentage Design
Pumps Starting Stage:
Pumps Ending Stage:
Average Temp:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Max BH Pressure:
ISDP:
Final 10 min:
Interval Status:
Flush Volume:
Average Rate:
Average Missile Pressure:
End Date/Time:
Initial Surface Pressure (Breakdown):
Initial Rate (Breakdown):
Conoco Phillips - CD4-586 Interval Summary 31
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Muted Dart Seat. Switched to last bin in 4ppg, staged up through the higher proppant
concentrations on calls from CoP.
Keegan Lambe
Nathan Brzezinski
David Martinez
*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.Baskoro Tejo
Chad Burkett
Conoco Phillips - CD4-586 Interval Summary 32
Hydraulic Fracturing Fluid Product Component Information Disclosure
2023-09-03
Alaska
HARRISON BAY
50-103-20857
CONOCOPHILLIPS
CD4 586
-150.9872
70.2923
NAD83
none
Oil
4371
959963
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%77.77098%8178885 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
LVT-200
Baker
Hughes Additive 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
SP BREAKER Halliburton Breaker Listed Below Listed Below 0
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%0.00069%73
2,7-Naphthalenedisulfonic acid, 3-
hydroxy-4-[(4-sulfor-1-
naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00004%5
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00134%141
C.I. Pigment Red 5 6410-41-9 1.00%0.00016%17
Confidential Proprietary 10.00%0.00013%15 ResMetrics Product Stewardship
info@resmetri
cs.com 8325921900
Confidential Proprietary 100.00%0.00269%283 ResMetrics Product Stewardship
info@resmetri
cs.com 8325921900
Corundum 1302-74-5 65.00%13.72669%1443585
Crystalline silica, quartz 14808-60-7 100.00%0.71791%75501
Cured acrylic resin Proprietary 1.00%0.00016%17
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
Distillates (petroleum),
hydrotreated light 64742-47-8 100.00%0.00000%0
Ethanol 64-17-5 60.00%0.04119%4332
Ethylene glycol 107-21-1 30.00%0.01246%1311
Glycol Ether Proprietary 85.00%0.00110%116 ResMetrics Product Stewardship
info@resmetri
cs.com 8325921900
Guar gum 9000-30-0 100.00%0.25857%27193
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.02060%2166
Hemicellulase 9025-56-3 5.00%0.00079%84
Monoethanolamine borate 26038-87-9 100.00%0.04154%4369
Mullite 1302-93-8 45.00%9.50309%999405
Naphthalene 91-20-3 5.00%0.00343%361
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02060%2166 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Oxyalkylated phenolic resin Proprietary 10.00%0.00687%722 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%0.00343%361
Polyamine Proprietary 30.00%0.00476%501 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Propylene Glycol 57-55-6 20.00%0.00027%29
Sodium chloride 7647-14-5 5.00%3.88862%408952
Sodium hydroxide 1310-73-2 30.00%0.00205%217
Sodium persulfate 7775-27-1 100.00%0.00000%0
Sodium sulfate 7757-82-6 0.10%0.00000%0
Walnut hulls NA 100.00%0.01585%1667 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com
281-871-
6226
Water 7732-18-5 100.00%0.02039%2145
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.3
All component information listed was obtained from the suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who
provided it. The Occupational Safety and Health Administrations (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this
information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D.
Production Type:
True Vertical Depth (TVD):
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
Well Name and Number:
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Fracture Date
State:
County:
API Number:
Operator Name:
Page 1/1
Procedure Closeout
CD4-586
Primary Job Type
SUPPORT OTHER OPERATIONS
Start Date
8/30/2023
End Date Final Job Status
IN PROGRESS
Total Time Log Hours (hr)
178.84
Summary
Network/Order Number Project Desc Estimator
10451713 CD4-586 - Frac - Frac
Start Date ZX Code Time Log Hrs (hr)
Cum Time Log
(days) Last 24hr Sum
8/30/2023 ZX02 Fracturing 17.99 0.75 LAID CONTAINMENT FOR THE TANK FARM, MOVED IN / RIGGED UP TANK FARM, CONSISTING OF 19 FRAC TANKS, HOSES AND
MANIFOLD
LOIL PRESSURE TEST MANIFOLD
PRELOADING PROPPANT
8/31/2023 ZX02 Fracturing 23.98 1.75 CONTINUED PRELOADING/STAGING PROPPANT, SPOTTED WATER HEATER, SPOTTED PROPPANT EQUIPMENT
PLACED CONTAINMENT, SPOTTED BLENDERS, STOOD SAND CASTLES, STAGED PUMPS
SWAPPED COIL TANK FOR FRAC PRV TANK,
STARTED LOADING PROPPANT
9/1/2023 ZX02 Fracturing 22.98 2.71 CONTINUED PROPPANT PRE LOADING/STAGING,
NIPPLE UP GOAT HEAD DART LAUNCH STACK AND ROTARY, HAMMERED UP RISER HARD LINE TO LAUNCH STACK, HAMMERED
UP FRAC HARD LINE RISER TO GOAT HEAD
SPOTTED PUMPS, HP MANIFOLD, SPOTTED CVA, BLEED MANIFOLD, COMPLETED IA,OA PRV LINES
LOADED PROPPANT, LOADED/ HEATED WATER
9/2/2023 ZX02 Fracturing 23.98 3.71 COMPLETED LOADING/HEATING WATER, COMPLETED RIG IN, STARTED AND FUNCTION TESTED EQUIPMENT.
FLOODED LINES, PRIMED EQUIPMENT, PRESSURE TEST PUMPS AND LINES, LEAK ON 2 2INCH CHIKSANS ON DART LAUNCH
LINE, SWAPPED AND RETESTED, GOOD TEST, 5 MINUTES LESS THAN 5% LOSS
9/3/2023 ZX02 Fracturing 23.98 4.70 PRIME EQUIPMENT,LOW PSI TEST, PRV TEST, PT, RUPTURE GLASS DISC, DROP BALL 1 GOOD BALL SEAT, PUMP DFIT, STEP
RATE, MINIFRAC, AND FRAC STAGES 1-4 TO DESIGN, STAGE 1 PUMPED 137,269 LB PROPPANT, STAGE 2 GOOD BALL SEAT,
PUMPED 134,892 LB PROPPANT, STAGE 3 GOOD SEAT, PUMPED 136,454 LB PROPPANT, STAGE 4 GOOD BALL SEAT, PUMPED
137,557 LB PROPPANT.
9/4/2023 ZX02 Fracturing 23.97 5.70 CONTINUE LOADING/HEATING WATER, COMPLETE LOADING PROPPANT
PUMPED STAGES 5-9 TO DESIGN, STAGE 5) GOOD BALL SEAT@18,208' PUMPED 134,944 LB PROPPANT, STAGE 6) GOOD BALL
SEAT @ 17,675' PUMPED 131,399 LB PROPPANT, STAGE 7) GOOD BALL SEAT@17,278PUMPED 134146 LB PROPPANT, STAGE 8)
GOOD BALL SEAT @16,880' PUMPED 135,797 LB PROPPANT STAGE 9) GOOD BALL SEAT @ 16,524' PUMPED 131,706 LB
PROPPANT
9/5/2023 ZX02 Fracturing 23.98 6.70 CONTINUE HEATING/LOADING WATER, COMPLETE PROPPANT LOADING, PUMP STAGES 10-14
STAGE 10) GOOD BALL SEAT @ 16,126' TOTAL PROPPANT PUMPED 3256 LB 100 MESH 129,170 20/40 , STAGE 11) GOOD BALL
SEAT @ 15,728' PROPPANT PUMPED 3421 LB 100 MESH, 130,390 20/40, STAGE 12) DART SHIFT OBSERVED MINIMAL PSI
CHANGE @ 15,378' PROPPANT PUMPED 3072 100 MESH, 129,401 20/40, STAGE 13) DART SHIFT OBSERVED MINIMAL CHANGE
@ 14,985' PROPPANT PUMPED 3025 LB 100 MESH, 128,594 LB 20/40, STAGE 14) MASKED SHIFT FORM PUMP RATE
FLUCTUATIONS PRESUMED SEAT @ 14,389, PROPPANT PUMPED 2769 LB 100 MESH, 128,991 LB 20/40
9/6/2023 ZX02 Fracturing 17.98 7.45 CONTINUED/COMPLETED LOADING/HEATING WATER, COMPLETED LOADING PROPPANT
PUMPED STAGES 15-17,
STAGE 15) GOOD DART SEAT 6 BBL EARLY @ 14,238.88', 233 JCV, PUMPED 128,564 LB PROPPANT,STAGE16) GOOD DART SEAT
3 BBL EARLY @13,928.77' 1534 JCV, PUMPED 131,857 LB PROPPANT, STAGE 17) NON VISIBLE DART SEAT SLIGHT CHANGE OF 3
PSI ON VOLUME @13,576' 2803 JCV PUMPED 83,628 LB PROPPANT
Hydraulic Fracturing Fluid Product Component Information Disclosure
Hydraulic Fracturing Fluid Composition:
Job Start Date:9/3/2023
Job End Date:9/6/2023
State:Alaska
County:Harrison Bay
API Number:50-103-20857-00-00
Operator Name:ConocoPhillips Company/Burlington
Resources
Well Name and Number:CD4-586
Latitude:70.29267500
Longitude:-150.98414500
Datum:NAD27
Federal Well:NO
Indian Well:NO
True Vertical Depth:4,371
Total Base Water Volume (gal):959,963
Total Base Non Water Volume:47,998
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)**
Comments
SEAWATER (SG
8.52)
Halliburton Base Fluid
Water 7732-18-5 100.00000 77.77098 Density = 8.52
Ingredients Listed Above Listed Above
Water 7732-18-5 100.00000 0.02039
WPT 1000-1050 ResMetrics Tracer
Listed Below
MO-67 Halliburton pH Control
Listed Below
GPT 3000-3014 ResMetrics Tracer
Listed Below
SP BREAKER Halliburton Breaker
Listed Below
LVT-200 Baker Hughes Additive
Listed Below
Ceramic
Proppant - Wanli
Wanli Proppant
Listed Below
Sand-Common
White-100 Mesh,
SSA-2
Halliburton Proppant
Listed Below
BC-140 X2 Halliburton Initiator
Listed Below
OPTIFLO-HTE Halliburton Breaker
Listed Below
LoSurf-300D Halliburton Non-ionic
Surfactant
Listed Below
BE-6(TM)
Bactericide
Halliburton Microbiocide
Listed Below
WG-36 GELLING
AGENT
Halliburton Gelling Agent
Listed Below
OPT 2000-2050 ResMetrics Tracer
Listed Below
Corundum 1302-74-5 65.00000 13.72669
Mullite 1302-93-8 45.00000 9.50309
Sodium chloride 7647-14-5 5.00000 3.88862
Crystalline silica, quartz 14808-60-7 100.00000 0.71791
Guar gum 9000-30-0 100.00000 0.25857
Monoethanolamine
borate
26038-87-9 100.00000 0.04154
Ethanol 64-17-5 60.00000 0.04119
Heavy aromatic
petroleum naphtha
64742-94-5 30.00000 0.02060
Oxyalkylated nonyl
phenolic resin
Proprietary 30.00000 0.02060
Walnut hulls 84012-43-1 100.00000 0.01585
Ethylene glycol 107-21-1 30.00000 0.01246
Oxyalkylated phenolic
resin
Proprietary 10.00000 0.00687
Items above are Trade Names with the exception of Base Water . Items below are the individual ingredients.
* Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water
** Information is based on the maximum potential for concentration and thus the total may be over 100%
*** If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.
Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS)
Polyamine Proprietary 30.00000 0.00476
Poly(oxy-1,2-ethanediyl),
alpha-(4-nonylphenyl)-
omega-hydroxy-,
branched
127087-87-0 5.00000 0.00343
Naphthalene 91-20-3 5.00000 0.00343
Confidential Proprietary 100.00000 0.00269
Sodium hydroxide 1310-73-2 30.00000 0.00205
2-Bromo-2-nitro-1,3-
propanediol
52-51-7 100.00000 0.00134
Glycol Ether Proprietary 85.00000 0.00110
Hemicellulase 9025-56-3 5.00000 0.00079
1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00069
Propylene Glycol 57-55-6 20.00000 0.00027
C.I. Pigment Red 5 6410-41-9 1.00000 0.00016
Cured acrylic resin Proprietary 1.00000 0.00016
Confidential Proprietary 10.00000 0.00013
2,7-
Naphthalenedisulfonic
acid, 3-hydroxy-4-[(4-
sulfor-1-naphthalenyl)
azo] -, trisodium salt
915-67-3 0.10000 0.00004
Sodium sulfate 7757-82-6 0.10000
Distillates (petroleum),
hydrotreated light
64742-47-8 100.00000
Sodium persulfate 7775-27-1 100.00000
Customer
Formation
Lease
API
Date
Well Summary
Wanli 20/40 Ceramic 100M Total Proppant
rface Press Rate Visc Temp pH rface Press Rate bbl gal bbl gal bbl gal bbl lbs lbs lbs
1 3315 23.7 24 83.3 8.5 3948 25.4 1,819 33,167 790 294 7 109,873 2,616 132,665 4,604 137,269
2 3287 24.1 23 84 8.5 3600 25.5 1,363 57,258 1,363 130,903 3,989 134,892
3 2911 24.0 26 85 8.5 3552 25.6 1,416 59,454 1,416 131,919 4,535 136,454
4 2754 24.5 23 85 8.5 3190 25.6 1,149 11,941 284 60,189 1,433 134,282 3,735 138,017
5 2896 24.0 24 86 8.4 3124 25.6 1,349 1,401 33 336 8 58,376 1,390 130,656 4,288 134,944
6 2705 23.6 24 86 8.4 3141 25.5 1,222 51,306 1,222 127,117 4,282 131,399
7 2744 23.4 22 87 8.4 3331 25.5 1,020 42,850 1,020 131,542 2,604 134,146
8 2640 23.5 23 86 8.4 2974 25.6 1,058 44,449 1,058 131,898 3,899 135,797
9 2472 24.5 23 86 8.4 2814 25.4 999 10,699 255 52,659 1,254 129,687 2,093 131,780
10 2282 24.2 23 87 8.3 2642 25.5 1,345 1,362 32 336 8 58,171 1,385 129,170 3,256 132,426
11 2327 22.1 23 87 8.4 2860 25.6 1,545 1,204 29 66,114 1,574 130,390 3,421 133,811
12 2315 23.3 23 87 8.4 3309 27.5 1,168 11,206 267 60,241 1,434 129,401 3,072 132,473
13 2434 23.3 23 87 8.5 3172 26.4 980 1,329 32 42,483 1,012 128,594 3,025 131,619
14 2378 23.4 22 87 8.5 3223 27.0 965 9,456 225 49,970 1,190 128,991 2,769 131,760
15 2335 23.9 23 88 8.4 2873 27.7 1,159 1,484 35 378 9 50,551 1,204 125,995 2,569 128,564
16 2229 23.7 23 84 8.5 2638 25.7 1,132 47,552 1,132 126,643 5,214 131,857
Minimum 952 1204 29 294 7 42483 1012 76129 2093 83628
Average 1214 8340 199 336 8 56468 1344 126822 3815 130637
Maximum 1819 33167 790 378 9 109873 2616 134282 7499 138017
Wanli 20/40 Ceramic 100M Total Proppant
Pressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl lbs lbs Total
Planned 19,429 114,263 2,721 4,000 95 934,283 22,245 2,210,000 69,000 2,278,000
Recorded 2721 23.7 23 86 8.43 3948 27.7 20,640 91,739 2,184 1,344 32 959,963 22,856 2,155,982 64,854 2,220,836
Weight Tickets 2,220,900 75,000 2,295,900
** Proppant is billed from Weight Ticket volumes
** IFS numbers for proppant are taken from software calculations based on
Total Fluid
Fluids Proppants
Fluids Proppants
Total Fluid
Average Max Seawater30# Delta Frac 30# Linear
30# Delta Frac 30# Linear
Interval Average Max Seawater
September 03, 2023
50-103-20857
CD4-586
Narwhal
Conoco Phillips
Conoco Phillips - CD4-586 Fluid System-Proppant Summary 33
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: _New Directional Plan_
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?CD4-586
Yes No
9. Property Designation (Lease Number): 10. Field:
Colville River, Narwhal Undefined Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name: Matt Nagel
Contact Email:
Contact Phone: 907-263-4747
Authorized Title: Drilling 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
matt.b.nagel@cop.com
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.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL384211, ADL380082, ADL380081, ADL391587
223-046
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20857-00-00
ConocoPhillips Alaska Inc
Length Size
Proposed Pools:
TVD BurstMD
Perforation Depth MD (ft): Perforation Depth TVD (ft):
7/10/2023
Perforate
Repair Wepair Well
Exploratory Stratigraphic Development Service
BOP TestMechanical Integrity Test
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 2:09 pm, Jul 13, 2023
323-396
DSR-7/13/23
X
VTL 07/17/2023
File w/ PTD 10-407
X
ALL CONDITIONS OF APPROVAL INCLUDED IN THE APPROVAL
OF THE ORIGINAL PTD 223-046 APPLY.
MDG 7/14/2023JLC 7/17/2023
07/18/23
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.07.18 00:06:55
-05'00'
RBDMS JSB 071823
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
July 13th, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Sundry for CRU CD4-586 Directional Change
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a change to the approve Permit to Drill (223-046) an onshore producer well from the CD4
drilling pad. The changes include a directional plan change. The spud date for this well was July 10th, 2023. The rig being used to drill this
well is Doyon Rig 26.
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 ~83°. 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 ~81°. 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, and CD4-588 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 a 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 CD4-586. 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 10-403
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:
CD4-586 Well File / Jenna Taylor ATO 1560
David Lee ATO 1726
Chris Brillon ATO 1548
Matt Nagel Andy Mack Kuukpik
Drilling Engineer
a change to the approve Permit to Drill (223-046)
AOGCC Sundry Reuqest, Well CD4-586
Saved: 13-Jul-23
CD4-586 AOGCC Sundry
Page 1 of 62 Printed: 13-Jul-23
CD4-586
AOGCC Application for Sundry
Directional Plan Change
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 Completion Schematic
Attachment 3 Property Plat
Attachment 4 Directional Plan CD4-586
AOGCC Sundry Reuqest, Well CD4-586
Saved: 13-Jul-23
CD4-586 AOGCC Sundry
Page 2 of 62 Printed: 13-Jul-23
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as CRU CD4-586.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface (CD4-586 Slot) 2466’ FSL, 4761’ FEL, Sec 19, T11N, R5E
NAD 27
Northings: 5957749
Eastings: 379436
RKB Elevation 73.5’ AMSL
Pad Elevation 19’ AMSL
Location at Productive Horizon (Heel) 538’ FNL, 738’ FEL, Sec 28, T11N, R5E
NAD 27
Northings: 5954420
Eastings: 389187
Measured Depth, RKB: 13,315’
Total Vertical Depth, RKB: 4,136’
Total Vertical Depth, SS: 4,063’
Location at Total Depth (Toe) 1415’ FNL, 551’ FEL, Sec 33, T11N, R5E
NAD 27
Northings: 5948206
Eastings: 393103
Measured Depth, RKB: 20,713’
Total Vertical Depth, RKB: 4,368’
Total Vertical Depth, SS: 4,294’
Requirements of 20 AAC 25.050(b)
Please see Attachment 5: CD4-586 wp7.1 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 Sundry Reuqest, Well CD4-586
Saved: 13-Jul-23
CD4-586 AOGCC Sundry
Page 3 of 62 Printed: 13-Jul-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 2,748 / 2,427 14.3 1,068 1,179
9-5/8 8,105 / 3,469 14.7 1,526 1,379
7 5/8 12,810 / 4,055 15.1 1,784 1,485
4-1/2 20,713 / 4,368 15.0 1,922 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
FPP = 0.44psi/ft x TVD above HRZ & 0.45psi/ft below HRZ unless otherwise specified
(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)
= 1,068 – (0.1 x 2,427) = 825 psi
2. Drilling Below 13-3/8” Surface Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(14.3 x 0.052) – 0.1] x 2,427’ = 1,562 psi
OR
ASP = FPP – (0.1 x D)
= 1,526 – (0.1 x 3,469’) = 1,179 psi
AOGCC Sundry Reuqest, Well CD4-586
Saved: 13-Jul-23
CD4-586 AOGCC Sundry
Page 4 of 62 Printed: 13-Jul-23
2. Drilling Below 9-5/8” Intermediate 3 Drilling Liner
ASP = [(FG x 0.052) – 0.1] x D
= [(14.7 x 0.052) – 0.1] x 3,469 = 2,305 psi
OR
ASP = FPP – (0.1 x D)
= 1,784 – (0.1 x 4,055) = 1,379 psi
6. Drilling Below 7-5/8” Intermediate 4 Drilling Liner
ASP = [(FG x 0.052) – 0.1] x D
= [(15.1 x 0.052) – 0.1] x 4,055 = 2,778 psi
OR
ASP = FPP – (0.1 x D)
= 1,922 – (0.1 x 4,368) = 1,485 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any hydrates nor gas zones. There are two potential
hydrocarbon zones that could be encountered in the intermediate 1 hole section including the Qannik and
C-10.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata,
lost circulation zones, and zones that have a propensity for differential sticking;
Please see Attachment 2 - Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c)(5))
Drill out casing or liner shoe and perform LOT or FIT in accordance with the COP ERD LOT / FIT
procedure that ConocoPhillips Alaska has on file with the Commission.
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing Program: Specifications Top Bottom Cement Quantity, sacks
Hole Casing Weig
ht
Grade Coup
ling
Length MD TVD MD TVD
42" 20" 94.0 H-40 Weld
ed
120 0 0 135 135 10 yds
16" 13.375" 68.0 L-80 H563 2748 0 0 2748 2427 1282sx 11 ppg & 334sx 15.8
ppg
12.25" 9.625" 47.0 T-95 H563 8105 0 0 8150 3469 813sx 15.8 ppg Class G (TOC
250’TVD above casing shoe)
8.5” x
9.5”
7.625” 29.7/
39.0
L-80/
P-110S
H523 4895 7955 3451 12810 4055 310sx 13ppg ext. lead, 123sx
15.8 ppg Class G (TOC
1500’MD above K3 sand)
6.5" 4.5" 12.6 P-110S H563 8053 12660 4034 20713 4368 Uncemented liner w/ frac
sleeves
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7))
CPAI requests a variance to the diverter requirement under 20 AAC 25.035 (h)(2) be granted.
At CD4, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval.
There are 3 previously drilled wells (CD4-499, CD4-320, CD4-292) within 500’ and 7 previously drilled wells
(CD4-291, CD4-209, CD4-290, CD4-289) within 1000’ of the proposed CD4-586 surface shoe location. None of
these wells encountered any significant indication of shallow gas or gas hydrates.
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CD4-586 AOGCC Sundry
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8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate
#1
Intermediate
#2 Production
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 11 9.5 8.6
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
11.0ppg 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.
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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.
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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 +/-2,748’ MD / 2,427’ 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 3-1/2” x 6-5/8” 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 / 2,500psi 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 / 3,500 psi. If the 21 day pressure testing cycle is not granted then the initial pressure test
will be performed to 250 psi low / 3,500 psi high for all components.
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 +/-8,105’ MD / 3,451’ TVD. Run MWD/LWD logging tools
(LMWD Program: GR/RES/DEN/NEU/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 +/-6,065’ MD / 3,219’ 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” DP string. RIH, clean out cement
to top of float equipment and
17. Drill out cement and 20' of new hole. Perform FIT to 11.5 ppg EMW minimum.
18. Install Managed Pressure Drilling (MPD) bearing assembly and displace to 9.5 ppg.
19. Directionally drill 8-1/2” x 9-1/2” Intermediate 2 hole to casing point at +/-12,810’ MD / 4,055’ 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 +/-9,638’ MD / 3,657’ 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
formations. Offset wells CD4-595, CD4-594, CD4-597, and CD4-588 have been approved by AOGCC on same
cement design.
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CD4-586 AOGCC Sundry
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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 +/- 20,713’ MD / 4,368’ TVD as per
directional plan. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/SON/DIR) in drill
string as required for directional monitoring and formation data gathering. Run Sonic log for 7.625” liner TOC
and report to AOGCC once it’s available.
27. Circulate well clean, flow check and backream out of hole to intermediate II shoe.
28. Displace to KW fluid and observe well for flow. Trip out of hole on elevators and lay down BHA.
29. PU and run 4-1/2” 12.6# P110S HYD563 lower completion, and line to TD.
30. PU and run 4-1/2” 12.6# L80 HYD563 tubing upper completion, circulate around with kill weight brine.
31. Land tubing.
32. Nipple down BOPE, nipple up tree and test against BPV.
33. Freeze protect 4-1/2” x 9-5/8” annulus with diesel.
34. Set BPV, secure well and move rig off.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
(Requirements of 20 AAC 25.005 (c)(14))
Drill cuttings and drilling mud form the well will be disposed of by hauling to Alpine injection facility where they
will be disposed by injecting to approved Class I or Class II Disposal wells.
15. Attachments
Attachment 1 Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Directional Plan
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Attachment 1 – Cement Summary
13-3/8” Surface Casing to 2,748’ MD / 2,427’ TVD
Cement from 2,748’ to 2,248' MD (500’) with 15.8ppg Class G tail and from 2,248' to surface with 11.0ppg
DeepCRETE lead. Assume 250% excess annular volume in Permafrost, 50% excess below the Permafrost, and
no excess within the 20” conductor.
Lead Slurry from 2,248’ MD to Surface with 11.0ppg DeepCRETE
Conductor (135’ – 55’) X 1.0454 ft3/ft X 1.0 (0% excess) = 84 ft3
Permafrost to Conductor (1,276’ – 135’) X 0.4206 ft3/ft X 3.5 (250% excess) = 1,680 ft3
Top of Tail to Permafrost (2,248’ – 1,276’) X 0.4206 ft3/ft X 1.5 (50% excess) = 613 ft3
Total Volume = 168 + 1,680 + 613 = 2,461 ft3 => 1,282 sx of 11.0ppg DeepCRETE @ 1.92 ft3 /sk
Tail Slurry from 2,748’ MD to 2,248’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (2,748’ – 2,248) X 0.4206 ft3/ft X 1.50 (50% excess) = 315 ft3
Shoe Joints (90’) X 0.8406 ft3/ft X 1.00 (0% excess) = 76 ft3
Total Volume = 315 + 76 = 391 ft3 => 334 sx of 15.8ppg Class G + additives @ 1.17 ft3/sk
9-5/8” Intermediate 1 Casing to 8,105’ MD / 3,469’ TVD
Cement from 8,150’ to 250’ TVD above the liner shoe with 15.8ppg Class G assuming 30% excess annular
volume.
Cement from 8,105’ MD to 6,065’ MD with 15.8ppg Class G + additives
Shoe to Top of Cement (8,105’ – 6,065’) X 0.313 ft3/ft X 1.40 (40% excess) = 894 ft3
Shoe Joint (120’) X 0.4110 ft3/ft X 1.00 (0% excess) = 49 ft3
Total Volume = 894 + 49 = 943 ft3 => 813 sx of 15.8ppg Class G + additives @ 1.16 ft3/sk
7-5/8” Intermediate 2 Liner to 12,810’ MD / 4,055’ TVD
COP requests to use 1500’MD above K3 sand. Cement from 12,810’ to 12,310’ (500’ MD) with 15.8 Class G
Tail and from 12,310’ to 9,638’ MD (1500’ above the K3 sand) with extended lead slurry.
Cement from 12,310’ MD to 9,638’ MD with 13 ppg Lead
12,310’ MD to Top of Cement (12,310’ – 9,638’) X 0.1751 ft3/ft X 1.3 (30% excess) = 608 ft3
Total Volume = 608 ft3 => 310 sx of 13ppg Class G + additives @ 1.96 ft3/sk
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CD4-586 AOGCC Sundry
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Tail Slurry from 12,810’ MD to 12,310’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (12,895’ – 12,395) X 0.1751 ft3/ft X 1.30 (30% excess) = 114 ft3
Shoe Joints (120’) X 0.2392 ft3/ft X 1.00 (0% excess) = 29 ft3
Total Volume = 114 + 29 = 143 ft3 => 123 sx of 15.8ppg Class G + additives @ 1.16 ft3/sk
CD4-586
Narwhal Lefty Sand Producer
with 7-5/8 INT2 (RKB = 73.5')
Surface Casing:
13-3/8" 68# L80 H563
2,748’ MD / 2,427 TVD – 54° Inc
Conductor Installed:
20" set @ 107' MD / TVD
Production Liner:
4-1/2" 12.6# P110S H563
12,660'-20,713' MD
Intermediate 1:
9-5/8" 47# T95 H563 @ 8,105 MD / 3,469' TVD – 83° Inc
Tubing:
12,745' 4-½” 12.6# L80 H563
12-1/4" Intermediate 1 Hole
6-1/2" Production Hole
16" Surface Hole
Narwhal LOL/Lefty Sand Top:
13,315' MD / 4,136' TVD
Intermediate 2:
7-5/8" 29.7# L80 H523
7-5/8" 39# TN110S H523 (680' heavy heel) w/ 29.7# Shoetrack
@ 12,810' MD / 4,055' TVD – 81° Inc
7-5/8" x 9-5/8" Liner hanger: 7,955’ MD' / 3,451' TVD
TOC @ 6,065' MD / 3,219' TVD
FMC Big Bore Well Head
Last Update: 7/10/23 MBN
DHG
TOC @ 9,638' MD / 3,657' TVD
K-3 Top: Possible Sand Stringers
11,138 MD / 3,840' TVD
Narwhal Central Sand Top:
12,907' MD / 4,071' TVD
4-½” Citadel MOAS Shoe
3.75" DB
3.813" X CMD
3.813" X Nipple
8-1/2” x 9-1/2” Under-Reamed
Intermediate 2 Hole
Production TD:
@ ± 20,713 MD / 4,368' TVD
4-1/2” x 7-5/8" ZXP Liner Top Packer 12,660' MD
4-1/2” x 7-5/8" Baker Flex Lock Liner hanger
DrilPlex WBM
10.5ppg
LSND WBM
10.8ppg
LSND WBM
9.0ppg
VersaPro OBM
8.2ppg
Diesel
6.8ppg
~2000' TVD
GLM
GLM
Brine
9.2ppg
CD4-586wp07.1
Production Packer
Oil swell packers and frac sleeves
PIKKA UNIT
COLVILLE RIVER UNIT
2
36
4
17
24
34
27
6
13
3
25
32
2120
16
31
30
19
18
28
22
15
1
5
29
33T11N, R4E, UMT11N, R5E, UMT10N, R4E, UMT10N, R5E, UMT10N, R5E, UM
T11N, R5E, UMCD2-57CD1-49CD4-24CD4
-
3
0
6CD4-9
3 CD1
-
4
8
CD4-208APB1CD4-214CD2
-53CD2-
2
7
CD2-77CD4-320PB1C
D
1
-
4
8
A
CD4-211
CD4-302
CD4-291PB1CD4-292CD4-291CD4-209NANUQ 5CD4-290CD4-320CD4
-
4
9
9 CD4-289CD4-298PB1
C
D
4
-
5
9
4
P
H
1CD4-301ACD4-298CD4-301C
D
4
-
5
9
5
P
H
CD4-03CD4-208ACD4-301BCD4-597CD4-595CD4
-
5
9
4
ADL388902
ADL372097
ADL392981
ADL380077
ADL391587
ADL393167
ADL392975
ADL393166
ADL384209
ADL372096
ADL392961
ADL380075
ADL380081
ADL380044
ADL388903
ADL384211
ADL380082
ADL384210
ADL391590
ADL393168
ADL380079
CD4
k
5/2/2023
S:\ANC\Longterm\AK GIS\WNS\DM\CRU_Wells\CD4\CD4_586\CD4-586_PTD_PRO\
CD4-586
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 CD4-586
55 300
300 490
490 670
670 860
860 1040
1040 1230
1230 1410
1410 1600
1600 2400
2400 3200
3200 4000
4000 4800
4800 5600
5600 6400
6400 7200
7200 8000
8000 9590
9590 11180
11180 12770
12770 14360
14360 15950
15950 17530
17530 19120
19120 20712
CD4-586 wp07.1 Plan Summary
0
4
Dogleg Severity0 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]
2321
2357
Nanuk 1
55101151201251301350400450499548598647696745
794
84389294198910381087113611841233128313331382143014791528157616251674
1723
1772
1822
1871CD4-588
55
68118168
218268
318367417466516564
CD4-289
55101151201251301350400450499548598647696745
794
84389294198910381087113611841233128313331382143014791528157616251674
1723
1772
1822
1871
CD4-588
5565115165215265315365415465514564614663713762812861910959100810581107
1155
1204
1253
CD4-587 wp07 (NE3A C)
0
2500
True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 121.70°
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7" Intermediate Casing 4-1/2" Production Liner
18
35
Centre to Centre Separation0 425 850 1275 1700 2125 2550 2975
Measured Depth
DDI
7.186
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
54.60 1200.00 CD4-586 wp07.1 (CD4-586) SDI_URSA1_I4
1200.00 2200.00 CD4-586 wp07.1 (CD4-586)MWD OWSG
1200.00 2740.00 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
2740.00 3740.00 CD4-586 wp07.1 (CD4-586) MWD OWSG
2740.00 8100.00 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
8100.00 9100.00 CD4-586 wp07.1 (CD4-586) MWD OWSG
8100.00 12800.00 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
12800.00 13800.00 CD4-586 wp07.1 (CD4-586) MWD OWSG
12800.00 20713.31 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
*URXQd / 18.90
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3468.88 8105.00 9-5/8" Intermediate Casing
4056.11 12810.00 7" Intermediate Casing
4368.00 20713.31 4-1/2" Production Liner
Mag Model & Date: BGGM2023 01-Sep-23
Magnetic North is 14.23° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.56° 57183.17nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 54.60 0.00 0.00 54.60 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 80.00 499.96 0.61 3.44 1.00 80.00 2.61 Start Build 2.00
4 700.00 6.00 80.00 699.43 3.03 17.17 2.00 0.00 13.02 Start Build 2.50
5 1227.92 19.20 80.00 1213.50 22.98 130.33 2.50 0.00 98.81 Start 105.89 hold at 1227.92 MD
6 1333.81 19.20 80.00 1313.50 29.03 164.62 0.00 0.00 124.81 Start Build 2.50
7 2708.12 53.56 80.00 2403.50 168.46 955.36 2.50 0.00 724.31 Start 20.00 hold at 2708.12 MD
8 2728.12 53.56 80.00 2415.38 171.25 971.20 0.00 0.00 736.33 Start DLS 2.50 TFO 48.75
9 4303.75 82.96 108.73 3003.22 24.34 2392.20 2.50 48.75 2022.53 Start 7877.01 hold at 4303.75 MD
1012180.77 82.96 108.73 3968.17 -2486.54 9795.69 0.00 0.00 9640.91 Start DLS 2.00 TFO 100.28
11 12646.33 81.40 118.00 4031.64 -2669.20 10218.63 2.00 100.2810096.74 Start 300.00 hold at 12646.33 MD
1212946.33 81.40 118.00 4076.50 -2808.46 10480.54 0.00 0.00 10392.74 CD4-NE3A (LL) T1 070323 Start 20.00 hold at 12946.33 MD
1312966.33 81.40 118.00 4079.49 -2817.75 10498.00 0.00 0.00 10412.48 Start DLS 3.00 TFO 93.90
1413231.79 80.10 123.22 4122.18 -2951.08 10723.42 2.00 104.5510674.33
1513436.40 80.10 123.22 4157.35 -3061.49 10892.05 0.00 0.00 10875.83
1613821.03 85.50 133.50 4205.66 -3298.05 11190.63 3.00 62.8411254.16 CD4-NE3A (LL) T2 070323
1714146.17 89.76 142.29 4219.13 -3538.80 11408.17 3.00 64.3511565.75
1815068.90 89.76 142.29 4223.03 -4268.74 11972.62 0.00 0.00 12429.56
1915307.65 89.00 147.00 4225.62 -4463.37 12110.73 2.00 99.1612649.34 CD4-NE3A (LL) T3 070323 Start DLS 2.00 TFO 116.32
2015464.65 88.48 150.10 4229.07 -4597.26 12192.62 2.00 99.5012789.36
2120713.31 88.48 150.10 4368.00 -9145.63 14808.25 0.00 0.0017404.79 CD4-NE3A (LL) T8 110822 TD at 20713.67
FORMATION TOP DETAILS
TVDPath Formation
1261.74 Base Perm
2214.97 C-40
2446.88 C-30
2769.67 C-20
3020.86 C-10
3233.68 Fault 1
3840.48 K-3
3934.72 K-3 FS1
3978.57 K-3 FS2
4014.99 K-3 FS3
4053.23 K-3 FS4
4070.55 Narwal Central Top
4136.43 LOL
4222.31 Lefty
4257.00 Fault 2
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 18.9+54.6 @ 73.50usft (D26)
-25000250050007500True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500Vertical Section at 121.70°13-3/8" Surface Casing9-5/8" Intermediate Casing7" Intermediate Casing4-1/2" Production Liner1000200030004000500060007000800090001000011000120001300014000150001600017000180001900020000207130°30°60°83°81°80°90°88°CD4-586 wp07.1Base PermC-40C-30C-20C-10Fault 1K-3K-3 FS1K-3 FS2K-3 FS3K-3 FS4Narwal Central TopLOLLeftyFault 2CD4-586 wp07.113:25, July 07 2023Section View
-8000-6000-4000-20000South(-)/North(+)0 2000 4000 6000 8000 10000 12000 14000West(-)/East(+)CD4-NE3A (LL) T3 070323CD4-NE3A (LL) T8 110822CD4-NE3A (LL) T2 070323CD4-NE3A (LL) T1 07032313-3/8" Surface Casing9-5/8" Intermediate Casing7" Intermediate Casing4-1/2" Production LinerCD4-586 wp07.1While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.13:29, July 07 20233ODQ9LHZ
0
35
Centre to Centre Separation0 500 1000 1500 2000 2500
Partial Measured Depth Nanuk 1CD4-588CD4-289CD4-588CD4-587 wp07 (NE3A C)CD4-586 wp07.1 Ladder View
0
150
300
Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000
Measured DepthNanuk 1CD4-588CD4-289CD4-290CD4-291CD4-291PB1CD4-292CD4-298CD4-298PB1CD4-301CD4-301ACD4-301BCD4-302CD4-499CD4-588CD4-594CD4-594PH1CD4-595CD4-595PH1CD4-597CD4-93CD4-93ACD4-96CD4-96ACD4-96APB1CD4-541 wp07 (NE4A C)CD4-587 wp07 (NE3A C)Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
54.60 1200.00 CD4-586 wp07.1 (CD4-586) SDI_URSA1_I4
1200.00 2200.00 CD4-586 wp07.1 (CD4-586) MWD OWSG
1200.00 2740.00 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
2740.00 3740.00 CD4-586 wp07.1 (CD4-586) MWD OWSG
2740.00 8100.00 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
8100.00 9100.00 CD4-586 wp07.1 (CD4-586) MWD OWSG
8100.0012800.00 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
12800.0013800.00 CD4-586 wp07.1 (CD4-586) MWD OWSG
12800.0020713.31 CD4-586 wp07.1 (CD4-586) MWD+IFR2+SAG+MS
14:33, July 07 2023
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3468.88 8105.00 9-5/8" Intermediate Casing
4056.11 12810.00 7" Intermediate Casing
4368.00 20713.31 4-1/2" Production Liner
55 500
500 800
800 1100
1100 1500
1500 1900
1900 2200
2200 2500
2500 3000
3000 4000
4000 4300
4300 4700
4700 14500
14500 17000
17000 21000
CD4-586 wp07.1 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]
2166
2207
2246
2284
2321
2357
2392
2426
2459
2491Nanuk 1
55
68118168
218268
318
367417466516564613662710
758
806
85490094999610441091113711841230128013291376CD4-289
55
68118
168218268
318367
416465515563611659707755
800
848
895
941
987
1032CD4-290
5568118168218268318367416
465514562
610658706753800846
893939985
CD4-291 5568118168218268318367416
465514562
610658706753800846
893939985
CD4-291PB1 55
68118168218268317366415464513561609656704750796842CD4-292
160716531700 1744
1789
1835 1880 1926 1973 2020 2067 2114 2161 2208 22563970
4018
4066
4112
4158
4202
4246
4288
4330
4372
4415
CD4-298
160716531700 1744
1789
1835 1880 1926 1973 2020 2067 2114 2161 2208 22563970
4018
4066
4112
4158
4202
4246
4288
4330
4372
4415
CD4-298PB1
55101151201251301350400450499548598647696745
794
8438929419891038108711361184123312831333138214301479152815761625167417231772
1822
1871
1920
1970
2019
2069
2119
2168
2218
2267
2317
2367
2417
2466
2516
2566CD4-588
55771271772272773263754244725205686156637107578048519009449911038108411311178
1225
1274
1323
CD4-594
55771271772272773263754244725205686156637107578048519009449911038108411311178
1225
1274
1323
CD4-594PH1
5568118168218268318366415464512560607654700748794CD4-93
5568118168218268317366415463512559607654700747793CD4-93A 556511516521526531536541546551456461466371376281286191095910081058110711551204
1253
1303
1352
1400
1449
1498
1546
1595
1643
1691
1739
1787
1835
1883
1930
14745147941484414893149431499215042150911513815186152351528315331153801542815477155271557715627156771572715777158271587715927159771602716077161271617716227162771632716377164271647716527165771662716677167271677716827168771692716977170271707717127171771722717277173271737717427174771752717577176271767717727177771782717877179271797718027180771812718176182261827618326183761842618476185261857618626186761872618776188261887618926CD4-587 wp07 (NE3A C)
55101151201251301350400450499548598647696745
794
8438929419891038108711361184123312831333138214301479152815761625167417231772
1822
1871
1920
1970
2019
2069
2119
2168
2218
2267
2317
2367
2417
2466
2516
2566CD4-588
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
From To Tool
54.60 1200.00 SDI_URSA1_I4
1200.00 2200.00 MWD OWSG
1200.00 2740.00 MWD+IFR2+SAG+MS
2740.00 3740.00 MWD OWSG
2740.00 8100.00 MWD+IFR2+SAG+MS
8100.00 9100.00 MWD OWSG
8100.00 12800.00 MWD+IFR2+SAG+MS
12800.00 13800.00 MWD OWSG
12800.00 20713.31 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3468.88 8105.00 9-5/8" Intermediate Casing
4056.11 12810.00 7" Intermediate Casing
4368.00 20713.31 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 54.60 0.00 0.00 54.60 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 80.00 499.96 0.61 3.44 1.00 80.00 2.61 Start Build 2.00
4 700.00 6.00 80.00 699.43 3.03 17.17 2.00 0.00 13.02 Start Build 2.50
5 1227.92 19.20 80.00 1213.50 22.98 130.33 2.50 0.00 98.81 Start 105.89 hold at 1227.92 MD
6 1333.81 19.20 80.00 1313.50 29.03 164.62 0.00 0.00 124.81 Start Build 2.50
7 2708.12 53.56 80.00 2403.50 168.46 955.36 2.50 0.00 724.31 Start 20.00 hold at 2708.12 MD
8 2728.12 53.56 80.00 2415.38 171.25 971.20 0.00 0.00 736.33 Start DLS 2.50 TFO 48.75
9 4303.75 82.96 108.73 3003.22 24.34 2392.20 2.50 48.75 2022.53 Start 7877.01 hold at 4303.75 MD
1012180.77 82.96 108.73 3968.17 -2486.54 9795.69 0.00 0.00 9640.91 Start DLS 2.00 TFO 100.28
11 12646.33 81.40 118.00 4031.64 -2669.20 10218.63 2.00 100.2810096.74 Start 300.00 hold at 12646.33 MD
1212946.33 81.40 118.00 4076.50 -2808.46 10480.54 0.00 0.0010392.74 CD4-NE3A (LL) T1 070323 Start 20.00 hold at 12946.33 MD
1312966.33 81.40 118.00 4079.49 -2817.75 10498.00 0.00 0.0010412.48 Start DLS 2.00 TFO 104.55
1413231.79 80.10 123.22 4122.18 -2951.08 10723.42 2.00 104.5510674.33 Start 204.61 hold at 13231.79 MD
1513436.40 80.10 123.22 4157.35 -3061.49 10892.05 0.00 0.0010875.83 Start DLS 3.00 TFO 62.84
1613821.03 85.50 133.50 4205.66 -3298.05 11190.63 3.00 62.8411254.16 CD4-NE3A (LL) T2 070323 Start DLS 3.00 TFO 64.35
1714146.17 89.76 142.29 4219.13 -3538.80 11408.17 3.00 64.3511565.75 Start 922.73 hold at 14146.17 MD
1815068.90 89.76 142.29 4223.03 -4268.74 11972.62 0.00 0.0012429.56 Start DLS 2.00 TFO 99.16
1915307.65 89.00 147.00 4225.62 -4463.37 12110.73 2.00 99.1612649.34 CD4-NE3A (LL) T3 070323 Start DLS 2.00 TFO 99.50
2015464.65 88.48 150.10 4229.07 -4597.26 12192.62 2.00 99.5012789.36 Start 5248.66 hold at 15464.65 MD
2120713.31 88.48 150.10 4368.00 -9145.63 14808.25 0.00 0.0017404.79 CD4-NE3A (LL) T8 110822 TD at 20713.31
CD4-586 wp07.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool54.60 1200.00 SDI_URSA1_I41200.00 2200.00 MWD OWSG1200.00 2740.00 MWD+IFR2+SAG+MS2740.00 3740.00 MWD OWSG2740.00 8100.00 MWD+IFR2+SAG+MS8100.00 9100.00 MWD OWSG8100.00 12800.00 MWD+IFR2+SAG+MS12800.00 13800.00 MWD OWSG12800.00 20713.31 MWD+IFR2+SAG+MSCASING DETAILSTVD MD Name2427.152748.0013-3/8" Surface Casing3468.888105.009-5/8" Intermediate Casing4056.1112810.007" Intermediate Casing4368.0020713.314-1/2" Production Liner1010202030304040505060600901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]22922307232123362350236423782392Nanuk 155587898118138158178198218238258278298318338357377397417437456476496516535555574594CD4-289556181101121141161181201221241261281301320340360380400420440459479499519539558578598617637657676696716735755775794814833853872892911931950970989100910281048106710871106112611451165118412041223124312631283130313231343136213821401142014401459147914981518153715571576159616161635165516741694171317331753177217921812183118511871189155557595115135155175195215235255275295315335355375395415435455475495514534554574594614634653673693713733752772792812831851871890910930950969989100810281048106710871107112611461165118512041224124412631283CD4-587 wp07 (NE3A C)5561811011211411611812012212412612813013203403603804004204404594794995195395585785986176376576766967167357557757948148338538728929119319509709891009102810481067108711061126114511651184120412231243126312831303132313431362138214011420144014591479149815181537155715761596161616351655167416941713173317531772179218121831185118711891CD4-58855 500500 800800 11001100 15001500 19001900 22002200 25002500 30003000 40004000 43004300 47004700 1450014500 1700017000 21000From Colour To MD54.60 To 2500.00MD Azi TFace54.60 0.00 0.00300.00 0.00 0.00500.00 80.00 80.00700.00 80.00 0.001227.92 80.00 0.001333.81 80.00 0.002708.12 80.00 0.002728.12 80.00 0.004303.75 108.73 48.7512180.77 108.73 0.0012646.33 118.00 100.2812946.33 118.00 0.0012966.33 118.00 0.0013231.79 123.22 104.5513436.40 123.22 0.0013821.03 133.50 62.8414146.17 142.29 64.3515068.90 142.29 0.0015307.65 147.00 99.1615464.65 150.10 99.5020713.31 150.10 0.00
CD4-586 wp07.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool54.60 1200.00 SDI_URSA1_I41200.00 2200.00 MWD OWSG1200.00 2740.00 MWD+IFR2+SAG+MS2740.00 3740.00 MWD OWSG2740.00 8100.00 MWD+IFR2+SAG+MS8100.00 9100.00 MWD OWSG8100.00 12800.00 MWD+IFR2+SAG+MS12800.00 13800.00 MWD OWSG12800.00 20713.31 MWD+IFR2+SAG+MSCASING DETAILSTVD MD Name2427.152748.0013-3/8" Surface Casing3468.888105.009-5/8" Intermediate Casing4056.1112810.007" Intermediate Casing4368.0020713.314-1/2" Production Liner20204040606080801001001201200901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [40 usft/in]24062419243324462459Nanuk 1406640844103412141394158417541934211422842464263427942964313433043474364CD4-29840664084410341214139415841754193421142284246426342794296431343304347436455 500500 800800 11001100 15001500 19001900 22002200 25002500 30003000 40004000 43004300 47004700 1450014500 1700017000 21000From Colour To MD2400.00 To 8200.00MD Azi TFace54.60 0.00 0.00300.00 0.00 0.00500.00 80.00 80.00700.00 80.00 0.001227.92 80.00 0.001333.81 80.00 0.002708.12 80.00 0.002728.12 80.00 0.004303.75 108.73 48.7512180.77 108.73 0.0012646.33 118.00 100.2812946.33 118.00 0.0012966.33 118.00 0.0013231.79 123.22 104.5513436.40 123.22 0.0013821.03 133.50 62.8414146.17 142.29 64.3515068.90 142.29 0.0015307.65 147.00 99.1615464.65 150.10 99.5020713.31 150.10 0.00
CD4-586 wp07.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool54.60 1200.00 SDI_URSA1_I41200.00 2200.00 MWD OWSG1200.00 2740.00 MWD+IFR2+SAG+MS2740.00 3740.00 MWD OWSG2740.00 8100.00 MWD+IFR2+SAG+MS8100.00 9100.00 MWD OWSG8100.00 12800.00 MWD+IFR2+SAG+MS12800.00 13800.00 MWD OWSG12800.00 20713.31 MWD+IFR2+SAG+MSCASING DETAILSTVD MD Name2427.152748.0013-3/8" Surface Casing3468.888105.009-5/8" Intermediate Casing4056.1112810.007" Intermediate Casing4368.0020713.314-1/2" Production Liner2525505075751001001251251501500901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [50 usft/in]55 500500 800800 11001100 15001500 19001900 22002200 25002500 30003000 40004000 43004300 47004700 1450014500 1700017000 21000From Colour To MD8000.00 To 12900.00MD Azi TFace54.60 0.00 0.00300.00 0.00 0.00500.00 80.00 80.00700.00 80.00 0.001227.92 80.00 0.001333.81 80.00 0.002708.12 80.00 0.002728.12 80.00 0.004303.75 108.73 48.7512180.77 108.73 0.0012646.33 118.00 100.2812946.33 118.00 0.0012966.33 118.00 0.0013231.79 123.22 104.5513436.40 123.22 0.0013821.03 133.50 62.8414146.17 142.29 64.3515068.90 142.29 0.0015307.65 147.00 99.1615464.65 150.10 99.5020713.31 150.10 0.00
CD4-586 wp07.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool54.60 1200.00 SDI_URSA1_I41200.00 2200.00 MWD OWSG1200.00 2740.00 MWD+IFR2+SAG+MS2740.00 3740.00 MWD OWSG2740.00 8100.00 MWD+IFR2+SAG+MS8100.00 9100.00 MWD OWSG8100.00 12800.00 MWD+IFR2+SAG+MS12800.00 13800.00 MWD OWSG12800.00 20713.31 MWD+IFR2+SAG+MSCASING DETAILSTVD MD Name2427.152748.0013-3/8" Surface Casing3468.888105.009-5/8" Intermediate Casing4056.1112810.007" Intermediate Casing4368.0020713.314-1/2" Production Liner2525505075751001001251251501500901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [50 usft/in]147451479414844148931494314992150421509115138151861523515283153311538015428154771552715577156271567715727157771582715877159271597716027160771612716177162271627716327163771642716477165271657716627166771672716777168271687716927169771702717077171271717717227172771732717377174271747717527175771762717677177271777717827178771792717977180271807718127181761822618276183261837618426184761852618576186261867618726187761882618876CD4-587 wp07 (NE3A C)55 500500 800800 11001100 15001500 19001900 22002200 25002500 30003000 40004000 43004300 47004700 1450014500 1700017000 21000From Colour To MD12800.00 To 20715.00MD Azi TFace54.60 0.00 0.00300.00 0.00 0.00500.00 80.00 80.00700.00 80.00 0.001227.92 80.00 0.001333.81 80.00 0.002708.12 80.00 0.002728.12 80.00 0.004303.75 108.73 48.7512180.77 108.73 0.0012646.33 118.00 100.2812946.33 118.00 0.0012966.33 118.00 0.0013231.79 123.22 104.5513436.40 123.22 0.0013821.03 133.50 62.8414146.17 142.29 64.3515068.90 142.29 0.0015307.65 147.00 99.1615464.65 150.10 99.5020713.31 150.10 0.00
CD4-586 wp07.1Spider Plot14:17, July 07 202354.60 To 20713.31Northing (4500 usft/in)Easting (4500 usft/in)353 739414345Nanuk 1353739 4143CD4-588353739414345CD4-033 53739414345
CD4-05353739414345CD4-073537394 14 34 5 CD4-123537394 14 34 5 CD4-12PB1353739414345Nanuq 5353739414345
CD4-163 53739414345
CD4-17353739414345CD4-208353739414345CD4-208A353739414345CD4-208AL1353739414345CD4-208APB1353739414345CD4-208PB1353739414345CD4-209353739414345CD4-210353739414345CD4-210A353739414345CD4-210APB1353739414345CD4-210B3 53739414345 CD4-2113 53739414345
CD4-211L13 53739414345
CD4-211L1-01353739414345CD4-213353 739414345 CD4-213A3 53739414345
CD4-213B3 53739414345
CD4-213BPB13 53739414345
CD4-213BPB23 53 73 94 14345 CD4-2143 53 73 94 14345
CD4-214L13 5373941434 5CD4-2153 5373941434 5CD4-215L13 53 73 9414 34 5
CD4-233 53 73 9414 34 5
CD4-23PB13 53 73 9414 34 5
CD4-23PB2353739414345CD4-24353739414345CD4-24PB1353739414345CD4-24PB2353739414345CD4-25353739414345CD4-25L1353739414345CD4-25PB13 53 7
3 94 14 3
4 5
CD4-26353739414345CD4-27353739414345CD4-27PB1353739414345CD4-27PB2353739414345CD4-27PB3353739414345CD4-289353739414345CD4-290353739414345CD4-291353739414345CD4-291PB1353739414345CD4-292353739414345 CD4-298353739414345 CD4-298PB1353739414345CD4-301353739414345CD4-301A353739414345CD4-301B353739414345CD4-302353739414345CD4-304353739414345CD4-304PB1353739414345CD4-306353739414345CD4-318353739414345CD4-318A353739414345CD4-318PB1353739414345CD4-319353739414345CD4-320353739414345CD4-320PB13 5
3 7
3 9
4 1
4 3
4 5
CD4-321353739414345CD4-32235373941CD4-49935373941CD4-539 wp06.1353739 41433537394143CD4-594353739414345CD4-594PH1353739414345CD4-595353739414345CD4-595PH13537394143CD4-597353739414345CD4-93353739414345CD4-93A353739414345CD4-96353739414345CD4-96A353739414345CD4-96APB13 53739414345
Nanuq 335373941CD4-529 wp0135373941CD4-530 wp0135373941CD4-531 wp0235373941CD4-532 wp0135373941CD4-533 wp0135373941CD4-534 wp0135373941CD4-535 wp0135373941CD4-536 wp023 5
3 739 41CD4-537 wp0235373941CD4-541 wp07 (NE4A C)3 5
3 739 41CD4-542 wp0135373941CD4-587 wp07 (NE3A C)3537394143CD4-586 wp07.1
CD4-586 wp07.1Spider Plot14:19, July 07 202354.60 To 20713.31Northing (2000 usft/in)Easting (2000 usft/in)2527293133353739414345Nanuk 12 5
2 7
2 9
3 1
3 3
3537 394143CD4-5882527293133353739414345CD4-032 5CD4-05CD4-0725272931333537394 14 34 5
CD4-1225272931333537394 14 34 5
CD4-12PB12527293133353739414345Nanuq 5CD4-16CD4-172527293133353739414345CD4-2082527293133353739414345CD4-208A2527293133353739414345CD4-208AL12527293133353739414345CD4-208APB12527293133353739414345CD4-208PB12527293133353739414345CD4-2092527293133353739414345CD4-21025272931333537394143CD4-210A25272931333537394143CD4-210APB125272931333537394143CD4-210B2 52729313335 CD4-2112 52729313335CD4-211L12 52729313335CD4-211L1-0125272931333537CD4-2132527293133353 7394 14345
CD4-213A2527
2 9CD4-213B2527293 1
CD4-213BPB125272931CD4-213BPB22 52 7CD4-2142 52 7CD4-214L1CD4-215CD4-215L12 52 7CD4-232 52 7CD4-23PB12 52 7CD4-23PB2252729CD4-24252729CD4-24PB1252729CD4-24PB225CD4-2525CD4-25L125CD4-25PB1CD4-26CD4-27CD4-27PB1CD4-27PB2CD4-27PB32527293 133353739414345 CD4-2892527293133353739414345CD4-2902527293133353739414345CD4-2912527293133353739414345CD4-291PB12527293133353739414345CD4-2922527293 1
33
353739
4 14345 CD4-2982527293 1
33
353739
4 14345 CD4-298PB12527293133353739414345CD4-3012527293133353739414345CD4-301A2527293133353739414345CD4-301B2527293133353739414345CD4-3022527CD4-3042527CD4-304PB12527CD4-306CD4-318CD4-318ACD4-318PB1252729CD4-3192527293133353739414345CD4-3202527293133353739414345CD4-320PB1CD4-321CD4-322252729313335373941CD4-499252729313335373941CD4-539 wp06.12 5
2 7
2 9
3 1
3 3
3537 3941432527293133353739CD4-5942527293133353739CD4-594PH12527293133CD4-5952527293133CD4-595PH125272931333537CD4-5972527CD4-932527CD4-93A2527CD4-962527CD4-96A2527CD4-96APB1Nanuq 3252729313335CD4-529 wp0125272931333537CD4-530 wp01252729313335CD4-531 wp02252729313335CD4-532 wp012527293133353739CD4-533 wp0125272931333537CD4-534 wp01252729313335373941CD4-535 wp01252729313335373941CD4-536 wp022 527
2 9
3 1
3 3
3 5
3 739 41CD4-537 wp022527
2 9
3 1
3 33537 3941CD4-541 wp07 (NE4A C)2 5
2 7
2 9
3 1
3 3
3 5
3 739 41CD4-542 wp01252729313335373941CD4-587 wp07 (NE3A C)2 52729 313335373941CD4-586 wp07.1
CD4-586 wp07.1Spider Plot14:20, July 07 202354.60 To 20713.31Northing (600 usft/in)Easting (600 usft/in)2 0222426283032343638404244Nanuk 12 0
2 2
2 4
2 6
2 8
3 0CD4-588202224CD4-03CD4-05CD4-072022242628CD4-122022242628CD4-12PB12022242628Nanuq 520222426283032343638404244CD4-208202224262830323436CD4-208A202224262830323436CD4-208AL1202224262830323436CD4-208APB120222426283032343638404244CD4-208PB1CD4-20920222426283032343638404244CD4-28920222426283032343638404244CD4-29020222426283032343638404244CD4-29120222426283032343638404244CD4-291PB120222426283032343638404244CD4-292202 2
24262830
32
3 4
363840
4244CD4-298202 2
24262830
32
3 4
363840
4244CD4-298PB12022242628303234363840CD4-3012022242628303234363840CD4-301A2022242628303234363840CD4-301B20222426283032343638404244CD4-302CD4-304CD4-304PB1CD4-30632343638404244CD4-32032343638404244CD4-320PB120222426283032 34363840CD4-49920222426283032CD4-539 wp06.12 0
2 2
2 4
2 6
2 8
3 0
2022242628CD4-5942022242628CD4-594PH120222426CD4-59520222426CD4-595PH12022242628CD4-597CD4-93CD4-93ACD4-96CD4-96ACD4-96APB12426CD4-530 wp012022242628CD4-531 wp022022242628CD4-532 wp012022242628CD4-533 wp012022242628CD4-534 wp01202224262830CD4-535 wp01202224262830CD4-536 wp022 02 2
2 4
2 6
28
3 0
3 2CD4-537 wp02202224262 8
3 0CD4-541 wp07 (NE4A C)2 0
2 2
2 4
2 6
2 8
3 0CD4-542 wp01202224262830CD4-587 wp07 (NE3A C)2 0
2 2
2 4
2628 3032CD4-586 wp07.1
CD4-586 wp07.1Spider Plot14:21, July 07 202354.60 To 20713.31Northing (80 usft/in)Easting (80 usft/in)246
8
1 0
1 2
1 4
1 6
1 8
2 0CD4-5882 4681012
1 4
1 6
182022 24CD4-28924 681012141618202224CD4-2902468101214 1618202224262830CD4-2912468101214 1618202224262830CD4-291PB124681012 141618202224CD4-29210121 4161820CD4-29810121 4161820CD4-298PB1121416CD4-301121416CD4-301A121416CD4-301B121416182022CD4-302CD4-3201 8
2 022242628 3032CD4-499246
8
1 0
1 2
1 4
1 6
1 8
2 0
2468 101214161820CD4-5942468 101214161820CD4-594PH12468101214CD4-5952468101214CD4-595PH181012CD4-59724681012CD4-9324681012CD4-93A2 2
2 4CD4-537 wp021 8
2 0
2 2
2 4CD4-542 wp012468101214161820CD4-587 wp07 (NE3A C)246
8
1 0
1 2
1 4
1 6
1 8
2 0CD4-586 wp07.1
CD4-586 wp07.1CD4-588CD4-289CD4-298CD4-298PB1CD4-301CD4-301ACD4-588CD4-594CD4-594PH1CD4-595PH1CD4-537 wp02CD4-541 wp07 (NE4A C)CD4-542 wp01CD4-587 wp07 (NE3A C)3-D ViewCD4-586 wp07.114:25, July 07 2023
CD4-586 wp07.1CD4-588CD4-289CD4-290CD4-291CD4-292CD4-298CD4-298PB1CD4-301CD4-301ACD4-302CD4-499CD4-588CD4-594PH1CD4-595PH1CD4-537 wp02CD4-541 wp07 (NE4A C)CD4-587 wp07 (NE3A C)3-D ViewCD4-586 wp07.114:24, July 07 2023
-10000-8000-6000-4000-20000South(-)/North(+) (2000 usft/in)6000 8000 10000 12000 14000 16000 18000 20000 22000West(-)/East(+) (2000 usft/in)4141414242424242CD4-588CD4-289CD4-290CD4-298CD4-298PB14141414242424242434343CD4-3014141414242424242434343CD4-301A4141414242424242434343CD4-301BCD4-302CD4-49941414142424242CD4-539 wp06.1414141424242424243434341424343CD4-5944141414242424242434343CD4-594PH14141414242424242434343CD4-5954141414242424242434343CD4-595PH141414142424242424343CD4-5974141414242424242CD4-531 wp024142CD4-532 wp01414142CD4-533 wp0141CD4-534 wp014141414242CD4-535 wp01414141424242CD4-536 wp02CD4-537 wp02414141CD4-541 wp07 (NE4A C)CD4-542 wp0141414242CD4-587 wp07 (NE3A C)41424242434343CD4-586 wp07.1CD4-586 wp07.1Quarter Mile View14:30, July 07 2023WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD ShapeCD4-NE3A (LL) T1 070323 4076.50 Circle (Radius: 100.00)CD4-NE3A (LL) T2 070323 4205.66 Circle (Radius: 100.00)CD4-NE3A (LL) T3 070323 4225.62 Circle (Radius: 100.00)CD4-NE3A (LL) T8 110822 4368.00 Circle (Radius: 100.00)CD4-NE3A T1 QM 4077.00 Circle (Radius: 1320.00)CD4-NE3A T6 QM 4245.00 Circle (Radius: 1320.00)CD4-NE3A T8 QM 4368.00 Circle (Radius: 1320.00)
CD4-586wp07.1 Surface Location
CD4-586wp07.1 Surface Location
CD4-586wp07.1 Surface Casing
CD4-586wp07.1 Surface Casing
CD4-586wp07.1 Intermediate Casing 1
CD4-586wp07.1 Intermediate Casing 1
CD4-586wp07.1 Intermediate Casing 2
CD4-586wp07.1 Intermediate Casing 2
CD4-586wp07.1 Top Production
CD4-586wp07.1 Top Production
CD4-586wp07.1 TD
CD4-586wp07.1 TD
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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
ConocoPhillips
P.O. Box 100360
Anchorage, AK, 99510
Re: Colville River, Narwhal Undefined Oil, CD4-586
ConocoPhillips
Permit to Drill Number: 223-046
Surface Location: 2466 FSL, 4761 FEL, Sec 19, T11N, R5E, UM
Bottomhole Location: 1415 FNL, 551 FEL, Sec 33, T11N, R5E, UM
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 AOGCC reserves
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 AOGCC specifically 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of June, 2023. 28
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2023.06.28
15:32:48 -05'00'
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: 20,712 TVD:4,368
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
8/1/2023
Total Depth:9. Acres in Property:14. Distance to Nearest Property:
551' to ADL392975
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 73.5 15. Distance to Nearest Well Open
Surface: x- -379436 y- 5957749 Zone- 4 18.9 to Same Pool: 1826' to CD4-594
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 89 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 94.0 H-40 Welded 120 0 0 135 135
16" 13.375" 68.0 L-80 Hyd563 2748 0 0 2748 2427
12.25" 9.625" 47.0 T-95 Hyd563 8150 0 0 8150 3469
8.5" x 9.5" 7.625" 29.7 / 39.0 L-80 / P-110S Hyd523 4895 8000 3451 12895 4055
6.5" 4.5" 12.6 P-110S Hyd563 7967 12745 3995 20712 4368
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:907-263-4747
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
CD4-586
Narwhal Undefined Oil
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.
Total Depth MD (ft): Total Depth TVD (ft):
59-52-180
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
823sx 15.8 ppg Class G
1485
615 FNL, 853 FEL, Sec 28, T11N, R5E, UM
1415 FNL, 551 FEL, Sec 33, T11N, R5E, UM
LONS 97-007
P.O. Box 100360 Anchorage, Alaska, 99510-0360
ConocoPhillips
2466 FSL, 4761 FEL, Sec 19, T11N, R5E, UM ADL384211, ADL380082, ADL380081, ADL391587
2485, 640, 640, 640
18. Casing Program: Top - Setting Depth - BottomSpecifications
1922
Cement Volume MDSize
Plugs (measured):
(including stage data)
10 yds
1282sx 11 ppg & 334sx 15.8 ppg
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):
294sx 13ppg ext. lead, 123sx 15.8 ppg C
Uncemented liner w/ frac sleeves
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
s 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 9:27 am, May 18, 2023
50-103-20857-00-00
x: 378447, y: 5957591
7/7/2023
Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig
Annular preventer test to 2500 psig
Diverter variance granted per 20 AAC 25.035(h)(2)
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.
MDG 6/28/2023
Colville River,
DSR-5/22/23
X
223-046
VTL 6/28/2023JLC 6/28/2023
06/28/23
06/28/23Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.06.28 15:33:09 -05'00'
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'
ϰͲϱϴϲ
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
May 17th, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill CD4-586
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the CD4 drilling pad. The intended spud date
for this well is August 1st, 2023. The intended rig used to drill the well is Doyon Rig 26.
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 ~83°. 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 ~81°. 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, and CD4-588 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 a 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 CD4-586. 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:
CD4-586 Well File / Jenna Taylor ATO 1560
David Lee ATO 1726
Chris Brillon ATO 1548
Matt Nagel Andy Mack Kuukpik
Drilling Engineer
*
*Recommend approval of requested diverter
variance: CD4-586 will be the 43rd well drilled from
the CD4 Pad, and it will be the 5th well drilled to the
Narwhal sand from this pad. Surface casing shoes of
Nanuk 1, CD4-594PH1, CD4-298, and CD4-302 all lie
within 500' from planned surface casing shoe of
CD4-586. The mudlogs and daily drilling operations
summaries for these wells do not report encountering
shallow gas or gas hydrates. MDG 6/28/2023
AOGCC Application for Permit to Drill, Well CD4-586
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CD4-586 AOGCC APD
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CD4-586
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 CD4-586
Attachment 6: Wellhead Schematic
AOGCC Application for Permit to Drill, Well CD4-586
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CD4-586 AOGCC APD
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1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as CRU CD4-586.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface (CD4-586 Slot) 2466’ FSL, 4761’ FEL, Sec 19, T11N, R5E
NAD 27
Northings: 5957749
Eastings: 379436
RKB Elevation 73.5’ AMSL
Pad Elevation 19’ AMSL
Location at Productive Horizon (Heel) 615’ FNL, 853’ FEL, Sec 28, T11N, R5E
NAD 27
Northings: 5954342
Eastings: 389301
Measured Depth, RKB: 13,450’
Total Vertical Depth, RKB: 4,138’
Total Vertical Depth, SS: 4,064’
Location at Total Depth (Toe) 1415’ FNL, 551’ FEL, Sec 33, T11N, R5E
NAD 27
Northings: 5948206
Eastings: 393103
Measured Depth, RKB: 20,712’
Total Vertical Depth, RKB: 4,368’
Total Vertical Depth, SS: 4,294’
Requirements of 20 AAC 25.050(b)
Please see Attachment 5: CD4-586 wp6.1 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.
corrected
see email
6/27/2023
5957591
378447
AOGCC Application for Permit to Drill, Well CD4-586
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CD4-586 AOGCC APD
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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 2,748 / 2,427 14.3 1,068 1,179
9-5/8 8,150 / 3,469 14.7 1,526 1,379
7 5/8 12,895/ 4,055 15.1 1,784 1,485
4-1/2 20,712 / 4,368 15.0 1,922 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
FPP = 0.44psi/ft x TVD above HRZ & 0.45psi/ft below HRZ unless otherwise specified
(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)
= 1,068 – (0.1 x 2,427) = 825 psi
2. Drilling Below 13-3/8” Surface Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(14.3 x 0.052) – 0.1] x 2,427’ = 1,562 psi
OR
ASP = FPP – (0.1 x D)
= 1,526 – (0.1 x 3,469’) = 1,179 psi
AOGCC Application for Permit to Drill, Well CD4-586
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2. Drilling Below 9-5/8” Intermediate 3 Drilling Liner
ASP = [(FG x 0.052) – 0.1] x D
= [(14.7 x 0.052) – 0.1] x 3,469 = 2,305 psi
OR
ASP = FPP – (0.1 x D)
= 1,784 – (0.1 x 4,055) = 1,379 psi
6. Drilling Below 7-5/8” Intermediate 4 Drilling Liner
ASP = [(FG x 0.052) – 0.1] x D
= [(15.1 x 0.052) – 0.1] x 4,055 = 2,778 psi
OR
ASP = FPP – (0.1 x D)
= 1,922 – (0.1 x 4,368) = 1,485 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any hydrates nor gas zones. There are two potential
hydrocarbon zones that could be encountered in the intermediate 1 hole section including the Qannik and
C-10.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata,
lost circulation zones, and zones that have a propensity for differential sticking;
Please see Attachment 2 - Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c)(5))
Drill out casing or liner shoe and perform LOT or FIT in accordance with the COP ERD LOT / FIT
procedure that ConocoPhillips Alaska has on file with the Commission.
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing Program: Specifications Top Bottom Cement Quantity, sacks
Hole Casing Weig
ht
Grade Coup
ling
Length MD TVD MD TVD
42" 20" 94.0 H-40 Weld
ed
120 0 0 135 135 10 yds
16" 13.375" 68.0 L-80 H563 2748 0 0 2748 2427 1282sx 11 ppg & 334sx 15.8
ppg
12.25" 9.625" 47.0 T-95 H563 8150 0 0 8150 3469 823sx 15.8 ppg Class G (TOC
250’TVD above casing shoe)
8.5” x
9.5”
7.625” 29.7/
39.0
L-80/
P-110S
H523 4895 8000 3451 12895 4055 294sx 13ppg ext. lead, 123sx
15.8 ppg Class G (TOC
1500’MD above K3 sand)
6.5" 4.5" 12.6 P-110S H563 7967 12745 3995 20712 4368 Uncemented liner w/ frac
sleeves
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7))
CPAI requests a variance to the diverter requirement under 20 AAC 25.035 (h)(2) be granted.
At CD4, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval.
There are 3 previously drilled wells (CD4-499, CD4-320, CD4-292) within 500’ and 7 previously drilled wells
(CD4-291, CD4-209, CD4-290, CD4-289) within 1000’ of the proposed CD4-586 surface shoe location. None of
these wells encountered any significant indication of shallow gas or gas hydrates.
There are two potentialpp yy g p
hydrocarbon zones that could be encountered in the intermediate 1 hole section including the Qannik andy
C-10.
AOGCC Application for Permit to Drill, Well CD4-586
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8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate
#1
Intermediate
#2 Production
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 11 9.5 8.6
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
11.0ppg 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.
gy (y g q ) p g
Mitigate wellbore instability with MPD targeting ~10 ppg EMW on connections.
AOGCC Application for Permit to Drill, Well CD4-586
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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 CD4-586
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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 +/-2,748’ MD / 2,427’ 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 3-1/2” x 6-5/8” 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 / 2,500psi 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 / 3,500 psi. If the 21 day pressure testing cycle is not granted then the initial pressure test
will be performed to 250 psi low / 3,500 psi high for all components.
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 +/-8,150’ MD / 3,451’ TVD. Run MWD/LWD logging tools
(LMWD Program: GR/RES/DEN/NEU/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 +/-6,083 MD / 3,219’ 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” DP string. RIH, clean out cement
to top of float equipment and
17. Drill out cement and 20' of new hole. Perform FIT to 11.5 ppg EMW minimum.
18. Install Managed Pressure Drilling (MPD) bearing assembly and displace to 9.5 ppg.
19. Directionally drill 8-1/2” x 9-1/2” Intermediate 2 hole to casing point at +/-12,895’ MD / 4,055’ 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 +/-9,811’ MD / 3,670’ 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
formations. Offset wells CD4-595, CD4-594, CD4-597, and CD4-588 have been approved by AOGCC on same
cement design.
AOGCC Application for Permit to Drill, Well CD4-586
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23. Test casing to 3850 psi for 30min.
24. Pick up 6-1/2” Bit and rotary steerable drilling assembly and RIH and clean out cement to top of float
equipment.
25.Drill out cement and 20' of new hole. Perform FIT to a minimum of 10 ppg EMW. Displace to 8.6 ppg NAF
drilling fluid.
26. Directionally drill 6-1/2” hole into the Narwhal Lefty Sand to TD at +/- 20,712’ MD / 4,368’ TVD as per
directional plan. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/SON/DIR) in drill
string as required for directional monitoring and formation data gathering. Run Sonic log for 7.625” liner TOC
and report to AOGCC once it’s available.
27. Circulate well clean, flow check and backream out of hole to intermediate II shoe.
28. Displace to KW fluid and observe well for flow. Trip out of hole on elevators and lay down BHA.
29. PU and run 4-1/2” 12.6# P110S HYD563 lower completion, and line to TD.
30. PU and run 4-1/2” 12.6# L80 HYD563 tubing upper completion, circulate around with kill weight brine.
31. Land tubing.
32. Nipple down BOPE, nipple up tree and test against BPV.
33. Freeze protect 4-1/2” x 9-5/8” annulus with diesel.
34. Set BPV, secure well and move rig off.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
(Requirements of 20 AAC 25.005 (c)(14))
Drill cuttings and drilling mud form the well will be disposed of by hauling to Alpine injection facility where they
will be disposed by injecting to approved Class I or Class II Disposal wells.
15. Attachments
Attachment 1 Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Directional Plan
e into the Narwhal Lefty Sand to TD
AOGCC Application for Permit to Drill, Well CD4-586
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Attachment 1 – Cement Summary
13-3/8” Surface Casing to 2,748’ MD / 2,427’ TVD
Cement from 2,748’ to 2,248' MD (500’) with 15.8ppg Class G tail and from 2,248' to surface with 11.0ppg
DeepCRETE lead. Assume 250% excess annular volume in Permafrost, 50% excess below the Permafrost, and
no excess within the 20” conductor.
Lead Slurry from 2,248’ MD to Surface with 11.0ppg DeepCRETE
Conductor (135’ – 55’) X 1.0454 ft3/ft X 1.0 (0% excess) = 84 ft3
Permafrost to Conductor (1,276’ – 135’) X 0.4206 ft3/ft X 3.5 (250% excess) = 1,680 ft3
Top of Tail to Permafrost (2,248’ – 1,276’) X 0.4206 ft3/ft X 1.5 (50% excess) = 613 ft3
Total Volume = 168 + 1,680 + 613 = 2,461 ft3 => 1,282 sx of 11.0ppg DeepCRETE @ 1.92 ft3 /sk
Tail Slurry from 2,748’ MD to 2,248’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (2,748’ – 2,248) X 0.4206 ft3/ft X 1.50 (50% excess) = 315 ft3
Shoe Joints (90’) X 0.8406 ft3/ft X 1.00 (0% excess) = 76 ft3
Total Volume = 315 + 76 = 391 ft3 => 334 sx of 15.8ppg Class G + additives @ 1.17 ft
3/sk
9-5/8” Intermediate 1 Casing to 8,150’ MD / 3,469’ TVD
Cement from 8,150’ to 250’ TVD above the liner shoe with 15.8ppg Class G assuming 30% excess annular
volume.
Cement from 8,150’ MD to 6,083’ MD with 15.8ppg Class G + additives
Shoe to Top of Cement (8,150’ – 6,083’) X 0.313 ft3/ft X 1.40 (40% excess) = 905 ft3
Shoe Joint (120’) X 0.4110 ft3/ft X 1.00 (0% excess) = 49 ft3
Total Volume = 905 + 49 = 955 ft3 => 823 sx of 15.8ppg Class G + additives @ 1.16 ft
3/sk
7-5/8” Intermediate 2 Liner to 12,895’ MD / 4,055’ TVD
COP requests to use 1500’MD above K3 sand. Cement from 12,895’ to 12,395’ (500’ MD) with 15.8 Class G
Tail and from 12,395’ to 9,811’ MD (1500’ above the K3 sand) with extended lead slurry.
Cement from 12,395’ MD to 9,811’ MD with 13 ppg Lead
12,395’ MD to Top of Cement (12,395’ – 9,811’) X 0.1751 ft3/ft X 1.3 (30% excess) = 576 ft3
Total Volume = 576 ft3 => 294 sx of 13ppg Class G + additives @ 1.96 ft
3/sk
COP requests to use 1500’MD above K3 sand.
AOGCC Application for Permit to Drill, Well CD4-586
Saved: 17-May-23
CD4-586 AOGCC APD
Page 10 of 62 Printed: 17-May-23
Tail Slurry from 12,895’ MD to 12,395’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (12,895’ – 12,395) X 0.1751 ft3/ft X 1.30 (30% excess) = 114 ft3
Shoe Joints (120’) X 0.2392 ft3/ft X 1.00 (0% excess) = 29 ft3
Total Volume = 114 + 29 = 143 ft3 => 123 sx of 15.8ppg Class G + additives @ 1.16 ft3/sk
CD4-586 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.
Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of
hole if 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 ~8.9 ppg. Narwhal Lefty Sand PP expected to be
~9.6 ppg. Central Sand and Lefty Sand may
communicate prior to drilling.
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.
gppg,
Narwhal Central Sand PP expected p
to be ~8.9 ppg. Narwhal Lefty Sand PP expected to be
~9.6 ppg. C
CD4-586
Narwhal Lefty Sand Producer
with 7-5/8 INT2 (RKB = 73.5')
Surface Casing:
13-3/8" 68# L80 H563
2,748’ MD / 2,427 TVD – 54° Inc
Conductor Installed:
20" set @ 107' MD / TVD
Production Liner:
4-1/2" 12.6# P110S H563
12,745'-20,712' MD
Intermediate 1:
9-5/8" 47# T95 H563 @ 8,150 MD / 3,469' TVD – 83° Inc
Tubing:
12,745' 4-½” 12.6# L80 H563
12-1/4" Intermediate 1 Hole
6-1/2" Production Hole
16" Surface Hole
Narwhal LOL/Lefty Sand Top:
13,450' MD / 4,138' TVD
Intermediate 2:
7-5/8" 29.7# L80 H523
7-5/8" 39# TN110S H523 (680' heavy heel) w/ 29.7# Shoetrack
@ 12,895' MD / 4,055' TVD – 81° Inc
7-5/8" x 9-5/8" Liner hanger: 8,000’ MD' / 3,451' TVD
TOC @ 6,083' MD / 3,219' TVD
FMC Big Bore Well Head
Last Update: 5/2/23 MBN
DHG
TOC @ 9,811' MD / 3,670' TVD
K-3 Top: Possible Sand Stringers
11,311 MD / 3,852' TVD
Narwhal Central Sand Top:
12,999' MD / 4,070' TVD
4-½” Citadel MOAS Shoe
3.75" DB
3.813" X CMD
3.813" X Nipple
8-1/2” x 9-1/2” Under-Reamed
Intermediate 2 Hole
Production TD:
@ ± 20,712 MD / 4,368' TVD
4-1/2” x 7-5/8" ZXP Liner Top Packer 12,745' MD
4-1/2” x 7-5/8" Baker Flex Lock Liner hanger
DrilPlex WBM
10.5ppg
LSND WBM
11.0ppg
LSND WBM
9.5ppg
VersaPro OBM
8.6ppg
Diesel
6.8ppg
~2000' TVD
GLM
GLM
Brine
9.2ppg
CD4-586wp06
Production Packer
Oil swell packers and frac sleeves
55 500
500 1000
1000 1300
1300 1700
1700 2250
2250 2400
2400 2700
2700 3700
3700 4000
4000 4300
4300 4700
4700 5500
5500 20712
CD4-586 wp06.1 Plan Summary
0
4
Dogleg Severity0 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
45.0
45.0
90.0
90.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in]
224622842321235723922426
Nanuk 1
55
68118168
218268
318367417466516564613662710
758
806
854902CD4-289
55
68118
168218268
318367
416465515563611659
CD4-290
5568118168218268CD4-2915568118168218268
5510015020025030035039944949954859764769674579484389294199010391088113711861235128513351383143214811529157816261675172417721820186919171966
CD4-588 wp04.1 - permit
551001502002503003503994494995495986486987477978478969469951045109511441194124312931342139214411491
CD4-587 wp06
0
2500
True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 121.70°
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7" Intermediate Casing
4-1/2" Production Liner
25
38
Centre to Centre Separation0 425 850 1275 1700 2125 2550 2975
Measured Depth
Equivalent Magnetic Distance
DDI
7.269
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
54.60 1200.00 CD4-586 wp06.1 (CD4-586) SDI_URSA1_I4
1200.00 2200.00 CD4-586 wp06.1 (CD4-586)MWD OWSG
1200.00 2740.00 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
2740.00 3740.00 CD4-586 wp06.1 (CD4-586) MWD OWSG
2740.00 8140.00 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
8140.00 9140.00 CD4-586 wp06.1 (CD4-586) MWD OWSG
8140.00 12890.00 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
12890.00 13890.00 CD4-586 wp06.1 (CD4-586) MWD OWSG
12890.00 20711.62 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
*round / 18.90
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3469.25 8150.00 9-5/8" Intermediate Casing
4054.75 12895.00 7" Intermediate Casing
4368.00 20711.62 4-1/2" Production Liner
Mag Model & Date: BGGM2022 01-Sep-23
Magnetic North is 14.28° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.54° 57173.52nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 54.60 0.00 0.00 54.60 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 80.00 499.96 0.61 3.44 1.00 80.00 2.61 Start Build 2.00
4 700.00 6.00 80.00 699.43 3.03 17.17 2.00 0.00 13.02 Start Build 2.50
5 1227.92 19.20 80.00 1213.50 22.98 130.33 2.50 0.00 98.81 Start 105.89 hold at 1227.92 MD
6 1333.81 19.20 80.00 1313.50 29.03 164.62 0.00 0.00 124.81 Start Build 2.50
7 2708.12 53.56 80.00 2403.50 168.46 955.36 2.50 0.00 724.31 Start 20.00 hold at 2708.12 MD
8 2728.12 53.56 80.00 2415.38 171.25 971.20 0.00 0.00 736.33 Start DLS 2.50 TFO 48.81
9 4309.06 83.05 108.85 3004.20 22.25 2397.01 2.50 48.81 2027.72 Start 7973.83 hold at 4309.06 MD
1012282.89 83.05 108.85 3969.65 -2534.54 9887.85 0.00 0.00 9744.54 Start DLS 2.00 TFO 100.88
11 12743.77 81.40 118.00 4032.14 -2715.79 10306.41 2.00 100.8810195.90 Start 300.00 hold at 12743.77 MD
1213043.77 81.40 118.00 4077.00 -2855.05 10568.31 0.00 0.00 10491.90 CD4-NE3A (LL) T1 110822 Start 20.00 hold at 13043.77 MD
1313063.77 81.40 118.00 4079.99 -2864.33 10585.77 0.00 0.00 10511.64 Start DLS 3.00 TFO 91.55
1413297.72 81.28 125.10 4115.27 -2985.26 10782.74 3.00 91.5510742.77 Start 216.75 hold at 13297.72 MD
1513514.47 81.28 125.10 4148.15 -3108.45 10958.02 0.00 0.00 10956.63 Start DLS 3.00 TFO 60.42
1613894.09 87.00 135.00 4187.00 -3351.15 11246.50 3.00 60.4211329.61 CD4-NE3A (LL) T4 110822 Start DLS 3.00 TFO 65.84
1714110.67 89.67 140.93 4193.30 -3511.87 11391.39 3.00 65.8411537.32 Start 752.35 hold at 14110.67 MD
1814863.02 89.67 140.93 4197.62 -4095.93 11865.60 0.00 0.00 12247.70 Start DLS 2.50 TFO 97.55
1915067.71 89.00 146.00 4200.00 -4260.33 11987.41 2.50 97.5512437.72 CD4-NE3A (LL) T5 110822 Start DLS 2.50 TFO 94.91
2015235.43 88.64 150.18 4203.45 -4402.64 12076.02 2.50 94.9112587.90 Start 1722.58 hold at 15235.43 MD
2116958.01 88.64 150.18 4244.20 -5896.70 12932.42 0.00 0.0014101.61 Start DLS 1.00 TFO -165.05
2216988.48 88.35 150.10 4245.00 -5923.11 12947.59 1.00 -165.0514128.39 CD4-NE3A (LL) T6 110822 Start DLS 1.00 TFO -157.26
2317014.94 88.11 150.00 4245.82 -5946.03 12960.79 1.00 -157.2614151.67 Start 3696.68 hold at 17014.94 MD
24 20711.62 88.11 150.00 4368.00 -9145.63 14808.25 0.00 0.0017404.79 CD4-NE3A (LL) T8 110822 TD at 20711.62
FORMATION TOP DETAILS
TVDPath Formation
1261.74 Base Perm
2214.96 C-40
2446.98 C-30
2764.14 C-20
3019.67 C-10
3233.87 Fault 1
3852.03 K-3
3929.70 K-3 FS1
3966.26 K-3 FS2
4003.93 K-3 FS3
4034.00 K-3 FS4
4070.30 Narwal Central Top
4138.43 LOL
4239.28 Fault 2
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 18.9+54.6 @ 73.50usft (D26)
-2500
0
2500
5000
7500True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 121.70°
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7" Intermediate Casing 4-1/2" Production Liner1000
2 0 0 0
30004000500060007000800090001000011000120001300014000150001600017000180001900020000207120°
3 0 °60°83°81°81°90°89°88°CD4-586wp06.1Base Perm
C-40
C-30
C-20
C-10
Fault 1
K-3
K-3 FS1
K-3 FS2
K-3 FS3
K-3 FS4 Narwal Central Top
LOL Fault 2
CD4-586 wp06.1 9:44, April 27 2023Section View
1C-40400
-8000
-6000
-4000
-2000
0
South(-)/North(+)0 2000 4000 6000 8000 10000 12000 14000
West(-)/East(+)
CD4-NE3A (LL) T2 110822
CD4-NE3A (LL) T5 110822
CD4-NE3A (LL) T4 110822
CD4-NE3A (LL) T1 110822
CD4-NE3A (LL) T7 110822
CD4-NE3A (LL) T8 110822
CD4-NE3A (LL) T3 110822
CD4-NE3A (LL) T6 110822
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7" Intermediate Casing
4-1/2" Production Liner
CD4-586 wp06.1
While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.
9:48, April 27 20233ODQ9LHZ
0
30
60
Centre to Centre Separation0 450 900 1350 1800 2250
Partial Measured Depth Nanuk 1CD4-289CD4-588 wp04.1 - permitCD4-587 wp06Equivalent Magnetic Distance
CD4-586 wp06.1 Ladder View
0
150
300
Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 2100
Measured DepthNanuk 1CD4-289CD4-290CD4-291CD4-291PB1CD4-292CD4-298CD4-298PB1CD4-301CD4-301ACD4-301BCD4-302CD4-588 wp04.1 - permitCD4-594CD4-594PH1CD4-595CD4-595PH1CD4-597CD4-93CD4-93ACD4-96CD4-96ACD4-96APB1CD4-587 wp06Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
54.60 1200.00 CD4-586 wp06.1 (CD4-586) SDI_URSA1_I4
1200.00 2200.00 CD4-586 wp06.1 (CD4-586) MWD OWSG
1200.00 2740.00 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
2740.00 3740.00 CD4-586 wp06.1 (CD4-586) MWD OWSG
2740.00 8140.00 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
8140.00 9140.00 CD4-586 wp06.1 (CD4-586) MWD OWSG
8140.00 12890.00 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
12890.00 13890.00 CD4-586 wp06.1 (CD4-586) MWD OWSG
12890.00 20711.62 CD4-586 wp06.1 (CD4-586) MWD+IFR2+SAG+MS
15:19, April 27 2023
CASING DETAILS
TVD MD Name2427.15 2748.0013-3/8" Surface Casing3469.25 8150.009-5/8" Intermediate Casing4054.75 12895.007" Intermediate Casing
4368.00 20711.624-1/2" Production Liner
55 500
500 1000
1000 1300
1300 1700
1700 2250
2250 2400
2400 2700
2700 3700
3700 4000
4000 4300
4300 4700
4700 5500
5500 20712
CD4-586 wp06.1 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]
216622072246
2284
2321
2357
2392
2426
2459
2491
Nanuk 1
55
68118168
218268
318367417466516564613662710
758
806
854902950996104410911137118412311280132913761422CD4-289
55
68118
168218268
318367
416465515563611659707
755
802
848
895
941
987
1032
1077
CD4-290
5568118168218268318367416
465514562
610658706753800846
8939399851031
CD4-291 5568118168218268318367416
465514562
610658706753800846
8939399851031
5568118168218268317366415464513561609656704750796842888
CD4-292
15621607165317001744
1789 1835 1880 1926 1973 2020 2067 2114 2161 2208 2256 2305
3921
3970
4018
4066
4112
4158
4202
4246
4288
4330
4372
4414
4457
CD4-298
15621607165317001744
1789 1835 1880 1926 1973 2020 2067 2114 2161 2208 2256 2305
3921
3970
4018
4066
4112
4158
4202
4246
4288
4330
4372
4414
4457
551001502002503003503994494995485976476967457948438929419901039108811371186123512851335138314321481152915781626167517241772182018691917196620142063211121592208
2256
2305
2353
2401
2450
2498
2547
2595
2644
2692
CD4-588 wp04.1 - permit
557712717722727732637542447252056861566371075780485089794499110381084113111781225
1274
1323
1370
1416
CD4-594
557712717722727732637542447252056861566371075780485089794499110381084113111781225
1274
1323
1370
1416
470517564611658705750
CD4-595
470517564611658705750
5568118168218268318366415464512560607654700748794840
CD4-93
5568118168218268317366415463512559607654700747793839
551001502002503003503994494995495986486987477978478969469951045109511441194
1243
1293
1342
1392
1441
1491
1540
1590
1639
1689
1738
1788
1837
1886
1936
CD4-587 wp06
SURVEY PROGRAM
Date: 2019-09-27T00:00:00 Validated: Yes Version:
From To Tool
54.60 1200.00 SDI_URSA1_I4
1200.00 2200.00 MWD OWSG
1200.00 2740.00 MWD+IFR2+SAG+MS
2740.00 3740.00 MWD OWSG
2740.00 8140.00 MWD+IFR2+SAG+MS
8140.00 9140.00 MWD OWSG
8140.00 12890.00 MWD+IFR2+SAG+MS
12890.00 13890.00 MWD OWSG
12890.00 20711.62 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3469.25 8150.00 9-5/8" Intermediate Casing4054.75 12895.00 7" Intermediate Casing
4368.00 20711.62 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 54.60 0.00 0.00 54.60 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 80.00 499.96 0.61 3.44 1.00 80.00 2.61 Start Build 2.00
4 700.00 6.00 80.00 699.43 3.03 17.17 2.00 0.00 13.02 Start Build 2.50
51227.92 19.20 80.00 1213.50 22.98 130.33 2.50 0.00 98.81 Start 105.89 hold at 1227.92 MD
61333.81 19.20 80.00 1313.50 29.03 164.62 0.00 0.00 124.81 Start Build 2.50
7 2708.12 53.56 80.00 2403.50 168.46 955.36 2.50 0.00 724.31 Start 20.00 hold at 2708.12 MD
8 2728.12 53.56 80.00 2415.38 171.25 971.20 0.00 0.00 736.33 Start DLS 2.50 TFO 48.81
9 4309.06 83.05 108.85 3004.20 22.25 2397.01 2.50 48.812027.72 Start 7973.83 hold at 4309.06 MD
1012282.89 83.05 108.85 3969.65 -2534.54 9887.85 0.00 0.009744.54 Start DLS 2.00 TFO 100.88
1112743.77 81.40 118.00 4032.14 -2715.7910306.41 2.00 100.8810195.90 Start 300.00 hold at 12743.77 MD
1213043.77 81.40 118.00 4077.00 -2855.0510568.31 0.00 0.0010491.90 CD4-NE3A (LL) T1 110822 Start 20.00 hold at 13043.77 MD
1313063.77 81.40 118.00 4079.99 -2864.3310585.77 0.00 0.0010511.64 Start DLS 3.00 TFO 91.55
1413297.72 81.28 125.10 4115.27 -2985.2610782.74 3.00 91.5510742.77 Start 216.75 hold at 13297.72 MD
1513514.47 81.28 125.10 4148.15 -3108.4510958.02 0.00 0.0010956.63 Start DLS 3.00 TFO 60.42
1613894.09 87.00 135.00 4187.00 -3351.1511246.50 3.00 60.4211329.61 CD4-NE3A (LL) T4 110822 Start DLS 3.00 TFO 65.84
1714110.67 89.67 140.93 4193.30 -3511.8711391.39 3.00 65.8411537.32 Start 752.35 hold at 14110.67 MD
1814863.02 89.67 140.93 4197.62 -4095.9311865.60 0.00 0.0012247.70 Start DLS 2.50 TFO 97.55
1915067.71 89.00 146.00 4200.00 -4260.3311987.41 2.50 97.5512437.72 CD4-NE3A (LL) T5 110822 Start DLS 2.50 TFO 94.91
2015235.43 88.64 150.18 4203.45 -4402.6412076.02 2.50 94.9112587.90 Start 1722.58 hold at 15235.43 MD
2116958.01 88.64 150.18 4244.20 -5896.7012932.42 0.00 0.0014101.61 Start DLS 1.00 TFO -165.05
2216988.48 88.35 150.10 4245.00-5923.1112947.59 1.00 -165.0514128.39 CD4-NE3A (LL) T6 110822 Start DLS 1.00 TFO -157.26
2317014.94 88.11 150.00 4245.82 -5946.0312960.79 1.00 -157.2614151.67 Start 3696.68 hold at 17014.94 MD
2420711.62 88.11 150.00 4368.00 -9145.6314808.25 0.00 0.0017404.79 CD4-NE3A (LL) T8 110822 TD at 20711.62
CD4-586 wp06.1 AC Flipbook
SURVEY PROGRAM
Depth From Depth To Tool
54.60 1200.00 SDI_URSA1_I4
1200.00 2200.00 MWD OWSG
1200.00 2740.00 MWD+IFR2+SAG+MS
2740.00 3740.00 MWD OWSG
2740.00 8140.00 MWD+IFR2+SAG+MS
8140.00 9140.00 MWD OWSG
8140.00 12890.00 MWD+IFR2+SAG+MS
12890.00 13890.00 MWD OWSG
12890.00 20711.62 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3469.25 8150.00 9-5/8" Intermediate Casing
4054.75 12895.00 7" Intermediate Casing
4368.00 20711.62 4-1/2" Production Liner
10
10
20
20
30
30
40
40
50
50
60
60
70
70
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]
55
6893118143168
193218243268
293318343367392417442466491516540564589613637
CD4-289
557510012515017520022525027530032535037439942444947449952354857359762264767169672074577079481984386889291794196699010151039106410881113113711611186121012351260128513101335135913831408143214561481
CD4-588 wp04.1 - permit
5575100125150175200225250275300325350375399424449474499524549574598623648673698723747772797822847871896921946
971
995
1020
1045
1070
1095
1119
1144
1169
1194
1218
1243
1268
1293
1318
1342
CD4-587 wp06
55 500
500 1000
1000 1300
1300 1700
1700 2250
2250 2400
2400 2700
2700 3700
3700 4000
4000 4300
4300 4700
4700 5500
5500 20712
From Colour To MD
54.60 To 1500.00
MD Azi TFace
54.60 0.00 0.00
300.00 0.00 0.00500.00 80.00 80.00
700.00 80.00 0.00
1227.92 80.00 0.00
1333.81 80.00 0.00
2708.12 80.00 0.00
2728.12 80.00 0.00
4309.06 108.85 48.81
12282.89 108.85 0.0012743.77 118.00 100.88
13043.77 118.00 0.00
13063.77 118.00 0.00
13297.72 125.10 91.55
13514.47 125.10 0.00
13894.09 135.00 60.42
14110.67 140.93 65.8414863.02 140.93 0.00
15067.71 146.00 97.55
15235.43 150.18 94.91
16958.01 150.18 0.00
16988.48 150.10 -165.05
17014.94 150.00 -157.26
20711.62 150.00 0.00
CD4-586 wp06.1 AC Flipbook
SURVEY PROGRAM
Depth From Depth To Tool
54.60 1200.00 SDI_URSA1_I4
1200.00 2200.00 MWD OWSG
1200.00 2740.00 MWD+IFR2+SAG+MS
2740.00 3740.00 MWD OWSG
2740.00 8140.00 MWD+IFR2+SAG+MS
8140.00 9140.00 MWD OWSG
8140.00 12890.00 MWD+IFR2+SAG+MS
12890.00 13890.00 MWD OWSG
12890.00 20711.62 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3469.25 8150.00 9-5/8" Intermediate Casing
4054.75 12895.00 7" Intermediate Casing
4368.00 20711.62 4-1/2" Production Liner
30
30
60
60
90
90
120
120
150
150
180
180
210
210
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
210321252146216621872207222722462266228423032321234023572375239224092426244324592475249125062521Nanuk 1
1513153615591582
16051628165016741696CD4-289
1517153915621585160716301653167616991721174417671789181218351858188019031926194919731996202020432067209021142137216121852208223222562281230523302355238024052430245524812506CD4-298
1517153915621585160716301653167616991721174417671789181218351858188019031926194919731996202020432067209021142137216121852208223222562281230523302355238024052430245524812506CD4-298PB1
15051529155415781602162616511675169917241748177217961820184518691893191719421966199020142038206320872111213521592184220822322256228023052329235323772401242624502474249825222547257125952619264426682692271627402764278728102833285628792902292529482971CD4-588 wp04.1 - permit
15081531155415771600162316451668169117141737CD4-594
15081531155415771600162316451668169117141737CD4-594PH1
151615401565159016151639166416891714173817631788181218371862188619111936196019852010203420592084CD4-587 wp06
55 500
500 1000
1000 1300
1300 1700
1700 2250
2250 2400
2400 2700
2700 3700
3700 4000
4000 4300
4300 4700
4700 5500
5500 20712
From Colour To MD
1500.00 To 3000.00
MD Azi TFace
54.60 0.00 0.00
300.00 0.00 0.00500.00 80.00 80.00
700.00 80.00 0.00
1227.92 80.00 0.00
1333.81 80.00 0.00
2708.12 80.00 0.00
2728.12 80.00 0.00
4309.06 108.85 48.81
12282.89 108.85 0.0012743.77 118.00 100.88
13043.77 118.00 0.00
13063.77 118.00 0.00
13297.72 125.10 91.55
13514.47 125.10 0.00
13894.09 135.00 60.42
14110.67 140.93 65.8414863.02 140.93 0.00
15067.71 146.00 97.55
15235.43 150.18 94.91
16958.01 150.18 0.00
16988.48 150.10 -165.05
17014.94 150.00 -157.26
20711.62 150.00 0.00
CD4-586 wp06.1 AC Flipbook
SURVEY PROGRAM
Depth From Depth To Tool
54.60 1200.00 SDI_URSA1_I4
1200.00 2200.00 MWD OWSG
1200.00 2740.00 MWD+IFR2+SAG+MS
2740.00 3740.00 MWD OWSG
2740.00 8140.00 MWD+IFR2+SAG+MS
8140.00 9140.00 MWD OWSG
8140.00 12890.00 MWD+IFR2+SAG+MS
12890.00 13890.00 MWD OWSG
12890.00 20711.62 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3469.25 8150.00 9-5/8" Intermediate Casing
4054.75 12895.00 7" Intermediate Casing
4368.00 20711.62 4-1/2" Production Liner
30
30
60
60
90
90
120
120
150
150
180
180
210
210
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
37663793381938453870
3896
3921
3945
3970
3994
4018
4042
4066
4089
4112
4135
4158
4180
4202
4224
4246
4267
4288
4309
4330
4351
4372
4393
4414
4436
4457
4478
4499
4521
CD4-298
37663793381938453870
3896
3921
3945
3970
3994
4018
4042
4066
4089
4112
4135
4158
4180
4202
4224
4246
4267
4288
4309
4330
4351
4372
4393
4414
4436
4457
4478
4499
4521
CD4-298PB1
3016CD4-588 wp04.1 - permit
4671
4694
4716
4739
4762
4785
4808
4830
4853
4876
4899
4922
4944
4967CD4-587 wp06
55 500
500 1000
1000 1300
1300 1700
1700 2250
2250 2400
2400 2700
2700 3700
3700 4000
4000 4300
4300 4700
4700 5500
5500 20712
From Colour To MD
3000.00 To 5500.00
MD Azi TFace
54.60 0.00 0.00
300.00 0.00 0.00500.00 80.00 80.00
700.00 80.00 0.00
1227.92 80.00 0.00
1333.81 80.00 0.00
2708.12 80.00 0.00
2728.12 80.00 0.00
4309.06 108.85 48.81
12282.89 108.85 0.0012743.77 118.00 100.88
13043.77 118.00 0.00
13063.77 118.00 0.00
13297.72 125.10 91.55
13514.47 125.10 0.00
13894.09 135.00 60.42
14110.67 140.93 65.8414863.02 140.93 0.00
15067.71 146.00 97.55
15235.43 150.18 94.91
16958.01 150.18 0.00
16988.48 150.10 -165.05
17014.94 150.00 -157.26
20711.62 150.00 0.00
CD4-586 wp06.1 AC Flipbook
SURVEY PROGRAM
Depth From Depth To Tool
54.60 1200.00 SDI_URSA1_I4
1200.00 2200.00 MWD OWSG
1200.00 2740.00 MWD+IFR2+SAG+MS
2740.00 3740.00 MWD OWSG
2740.00 8140.00 MWD+IFR2+SAG+MS
8140.00 9140.00 MWD OWSG
8140.00 12890.00 MWD+IFR2+SAG+MS
12890.00 13890.00 MWD OWSG
12890.00 20711.62 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2427.15 2748.00 13-3/8" Surface Casing
3469.25 8150.00 9-5/8" Intermediate Casing
4054.75 12895.00 7" Intermediate Casing
4368.00 20711.62 4-1/2" Production Liner
30
30
60
60
90
90
120
120
150
150
180
180
210
210
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
55 500
500 1000
1000 1300
1300 1700
1700 2250
2250 2400
2400 2700
2700 3700
3700 4000
4000 4300
4300 4700
4700 5500
5500 20712
From Colour To MD
5500.00 To 20712.00
MD Azi TFace
54.60 0.00 0.00
300.00 0.00 0.00500.00 80.00 80.00
700.00 80.00 0.00
1227.92 80.00 0.00
1333.81 80.00 0.00
2708.12 80.00 0.00
2728.12 80.00 0.00
4309.06 108.85 48.81
12282.89 108.85 0.0012743.77 118.00 100.88
13043.77 118.00 0.00
13063.77 118.00 0.00
13297.72 125.10 91.55
13514.47 125.10 0.00
13894.09 135.00 60.42
14110.67 140.93 65.8414863.02 140.93 0.00
15067.71 146.00 97.55
15235.43 150.18 94.91
16958.01 150.18 0.00
16988.48 150.10 -165.05
17014.94 150.00 -157.26
20711.62 150.00 0.00
CD4-586 wp06.1 Spider Plot
13:51, April 27 2023
54.60 To 20711.62
Northing (4500 usft/in)Easting (4500 usft/in)40506070Nan uk 14 0
5 0
60
70
CD4-0340506070CD4-0540506070CD4-074
0
50
6
0
70
CD4-124
0
50
6
0
70
CD4-12PB14 0
5 0
6 0
7 0Na nuq 540506070CD4-1640506070CD4-174 0
506 0CD4-20840
5 0
6 0
70
CD4-208A40
5 0
6 0
70CD4-208AL140
50
60
7 0
CD4-208APB14 0
506 0CD4-208PB1405060
CD4-2094
0
5060CD4-21040
50
60
70
CD4-210A40
50
60
70
CD4-210APB140
50
60
70
CD4-210B405
060
CD4-211405
060CD4-211L1405
060CD4-211L1-0140
5060CD4-2134
05
06
07
0CD4-213A40506070CD4-213B40506070CD4-213BPB140506070CD4-213BPB24
05
0
6 0
CD4-2144
05
0
6 0CD4-214L1405
0
6 0
CD4-215405
0
6 0CD4 -215L14
0
506070
CD4-234
0
5
0
6
0
70
CD4-23PB14
0
506070
CD4-23PB240
50
60
70CD4-2440
50
60
70CD4-24PB140
50
60
70CD4-24PB240
50
60
70CD4-2540
50
60
70CD4-25L140
50
6070CD4-25PB140506070CD4-2640
50
60
70
CD4-2740
50
60
70
CD4-27PB140
50
60
70
CD4-27PB240
50
60
70
CD4-27PB3405060CD4-28940506 0
CD4-29040506 0
CD4-29140506 0
CD4-291PB14 050
6 0
CD4-292405060CD4-298405060CD4-298PB1405060CD4-301405060 CD4-301A405060CD4-301B40506070CD4-30240506070CD4-30440506070CD4-304PB140506070CD4-3064
0
5
0
6
070CD4-3184
0
5
0
6
070CD4-318A4
0
5
0
6
0
7 0CD4-318PB140
50
6070CD4-31940
5060
7 0
CD4-32040
506 07 0CD 4-320PB140506070CD4-32140506070CD4-32240
CD4-4994 0
CD4-588 wp04.1 - permit40CD4-59440CD4-594PH140CD4-59540CD4-595PH140
CD4-59740506
0
70
CD4-9340506
0
70
CD4-93A4
0
5
0
6
0
70CD4 -964
0
5
0
6
0
70
CD4-96A4
0
5
0
6
0
70
CD4-96APB140506070Nanuq 34 0
CD4-529 wp014 0
CD4-530 wp0140CD4-531 wp024 0
CD4-532 wp0140CD4-533 wp014 0
CD4-534 wp0140CD4-535 wp0140CD4-536 wp0240CD4-537 wp0240CD4-539 wp0540CD4-540 wp0240CD4-541 wp014 0
CD4-542 wp014 0
CD4-587 wp0640CD4-586 wp06.1
CD4-586 wp06.1 Spider Plot
13:51, April 27 2023
54.60 To 20711.62
Northing (1500 usft/in)Easting (1500 usft/in)2025303540455055606570
7
5Na nuk 120
25
30
35
40
45CD4 -0320CD4-0520CD4-072 0
2 5
30
35
4
0
4
5CD4-122 0
2 5
30
35
4
0
4
5CD4-12PB12 0
2 5
3 0
3 5
4 0
4 5
5 0Na nuq 5CD4-16CD4-172 0
2 5
3 0
3 5
4 0
45
50556 0CD4-2082 0
2 5
30
35
40
45
5 0
5 5
CD4-208A2 0
2 5
30
35
40
45
5 0
5 5
CD4-208AL12 0
2 5
30
35
40
45
50
55
CD4-208APB12 0
2 5
3 0
3 5
4 0
45
50556 0CD4-208PB120253035
4045
5055
6 0
CD4-20920
25
3035CD4-21020
25
30
35CD4-210A20
25
30
35CD4-210APB120
25
30
35CD4-210B2025CD4-2112025CD4-211L12025CD4-211L1-0120
25
30CD4-21320
25
30
3
5
4
0
4
55
0CD4-213A20
2
5CD4-213B20
25
CD4-213BPB120
25
CD4-213BPB22
0CD4-2142
0CD4-214L120CD4-21520CD4-215L12
0CD4-232
0CD4-23PB12
0CD4-23PB220
25CD4 -2420
25CD4 -24PB120
25CD4-24PB220
CD4-2520
CD4-25L120
CD4-25PB12
0CD4 -2620CD4 -2720CD4 -27PB120CD4 -27PB220CD4 -27PB3202530354045505560CD4-28920253035404550556 0
CD4-29020253035404550556 0
CD4-29120253035404550556 0
CD4-291PB12 025303540455055
6 0
CD4-292202530354045505560CD4-298202530354045505560CD4-298PB120253035404550556065 CD4-301202530354045505
560
65CD 4-301A202530354045505
5
60
65CD4-301B2025303540455055606570CD4-3022025CD4-3042025CD4-304PB12025CD4-306CD4-318CD4-318ACD4-318PB120
25CD4 -31920
25
30
35
40
4550556 0
6 5
7 0
CD4-32020
25
30
35
40
45
5055 606 5
7 0CD 4-320PB1CD4-321CD4-3222025303540CD4-499202530354 0
CD4-588 wp04.1 - permit20253035CD4-59420253035CD4-594PH1202530CD4-595202530CD4-595PH120
25
3035 CD4-5972025CD4-932025CD4-93A20
2
5CD4-9620
2
5CD4-96A20
2
5CD4-96APB1Nanuq 320
25
3 0
CD4-529 wp012 0
2 5
3 0
3 5
CD4-530 wp01202530CD4-531 wp022 0
2 5
3 0
CD4-532 wp0120253035CD4-533 wp0120253 0
3 5CD4-534 wp012025303540CD4-535 wp012025303540CD4-536 wp022
0 25303540CD4-537 wp022025303540CD4-539 wp052025303540CD4-540 wp022
0
2
5 3035CD4-541 wp0120253035CD4-542 wp01202530354 0
CD4-587 wp062025303540CD4-586 wp06.1
CD4-586 wp06.1 Spider Plot
13:51, April 27 2023
54.60 To 20711.62
Northing (450 usft/in)Easting (450 usft/in)2025303540455055606570
7
5N anuk 120
CD4-0320CD4-0520CD4-072 0
CD4-122 0
CD4-12PB12 0
Nanuq 5CD4-16CD4-172 0
2 5
3 0
3 560CD4-2082 0
25
30
CD4-208A2 0
25
30
CD4-208AL12 0
25
30
CD4-208APB12 0
2 5
3 0
3 560CD4-208PB120
25
30
35
40
45
50
5 5
CD4-20920
25
30CD4-21020
25
30CD4-210A20
25
30CD4-210APB120
25
30CD4-210B2025CD4-2112025CD4-211L12025CD4-211L1-0120
25
CD4-21320
25
30
CD4-213A20
2
5CD4-213B20
25
CD4-213BPB120
25
CD4-213BPB220CD4-21420CD4-214L1CD4-215CD4-215L12
0
CD4-232
0
CD4-23PB12
0
CD4-23PB220
CD4-2420
CD4-24PB120
CD4-24PB220CD4-2520CD4-25L120CD4-25PB1CD4-26CD4-27CD4-27PB1CD4-27PB2CD4-27PB32025303540455055CD4-28920253035404550556 0
CD4-29020253035404550556 0
CD4-29120253035404550556 0
CD4-291PB12 0
2 5
3 0
3 5
4 0
4 5
5 0
5 5
6 0
CD4-29220253035CD4-29820253035CD4-298PB1202530CD4-301202530CD4-301A202530CD4-301B202530354045CD4-30220CD4-30420CD4-304PB120CD4-306CD4-318CD4-318ACD4-318PB120
CD4-31920
25
30
35
40
45
5055 6 0
6 5
7 0
CD4-32020
25
30
35
40
45
5055 606 5
7 0
CD4-320PB1CD4-321CD4-3222025303540CD4-4992025CD4-588 wp04.1 - permit2025CD4-5942025CD4-594PH12025CD4-5952025CD4-595PH120
25
CD4-59720CD4-9320CD4-93A20
2
5CD4-9620
2
5CD4-96A20
2
5CD4-96APB1Nanuq 320
25CD4-529 wp012 0
2 5
CD4-530 wp0120
25CD4-531 wp022 0
2 5
CD4-532 wp012025CD4-533 wp012025CD4-534 wp01202530CD4-535 wp01202530CD4-536 wp022
0 2530CD4-537 wp022025CD4-539 wp05202530CD4-540 wp022
0
2
5 30CD4-541 wp012025CD4-542 wp012025CD4-587 wp06202530CD4-586 wp06
CD4-586 wp06.1 Spider Plot
13:51, April 27 2023
54.60 To 20711.62
Northing (90 usft/in)Easting (90 usft/in)24681012141618202224262830323436384042444648 Nanuk 12468
1
0
1
2 141618202224CD4-2892
46
8
1 0
1214161820222426CD4-29024681
0 1214161820222426283032CD4-29124681
0 1214161820222426283032CD4-291PB124
6
8101 2
1 4
1 6
1 8
2 0
2 2
2 4
2 6
CD4-292101214161820CD4-298101214161820CD4-298PB11012141618CD4-3011012141618CD4-301A1012141618CD4-301B121416182022CD4-302CD4-320182022242628303234CD4-499246 810121416182022CD4-588 wp04.1 - permit2468101214161820CD4-524681012141618202468101214CD4-5952468101214CD4-595PH168101214CD4-597246
8
1 0
1 2CD4-93246
8
1 0
1 2CD4-93A2
22
4CD4-537 wp0220222426CD4-540 wp022
0
2
2
2
4
CD4-541 wp0118202224CD4-542 wp0124 68101214161820CD4-587 wp062
468101214161820CD4-586 wp06
CD4-586 wp06.1
CD4-289
CD4-298CD4-298PB1
CD4-301
CD4-301A
CD4-301B
CD4-588 wp04.1 - permit
CD4-594PH1
CD4-595PH1
CD4-537 wp02
CD4-540 wp02
CD4-541 wp01
CD4-542 wp01
CD4-587 wp06
3-D ViewCD4-586 wp06.1 14:41, April 27 2023
-10000
-8000
-6000
-4000
-2000
0
South(-)/North(+) (2000 usft/in)6000 8000 10000 12000 14000 16000 18000 20000 22000
West(-)/East(+) (2000 usft/in)
C D 4 -2 8 9CD4-2 9 0
C D 4 -2 9 8CD4-2 9 8 P B 1404141424243 C D 4 -3 0 1
404141424243C D 4 -3 0 1 A
404141424243C D 4 -3 0 1 B
CD4-302C D 4 -4 9 9
4 0
4 1
4 1
4 2
4 2
4 3
C D 4 -5 8 8 w p 0 4 .1 - p e rm it404141424 2
4 3
C D 4 -5 9 4404141424243CD4-594PH140414 14 24 24 3
C D 4 -5 9 5404141424243CD4-595PH140
41414 2
4 2
4 3
C D 4 -59 7404141
4 2
4 2
C D 4 -5 3 1 w p 0 2
C D 4 -5 3 2 w p 0 141
42
C D 4 -5 3 3 w p0 1
C D 4 -5 3 4 w p 0 14041 4 1
4 2
C D 4 -5 3 5 w p 0 1404141
4 2
C D 4 -5 3 6 w p 0 240 414 1
C D 4 -5 3 7 w p 0 2
40414 1
424 2
C D 4 -5 3 9 w p 0 5
4 2
4 2
4 3
C D 4 -5 4 0 w p 0 2
4 2
4 3
C D 4 -5 4 1 w p 0 1
4 1
C D 4 -5 4 2 w p 0 1
4 0
4 1
4 1
C D 4 -5 8 7 w p 0 64041414242
4 3
C D 4 -5 8 6 w p 0 6 .1
CD4-586 wp06.1
Quarter Mile View
14:43, April 27 2023 WELLBORE TARGET DETAILS (MAP CO-ORDINATES)
Name TVD Shape
CD4-NE3A (LL) T1 110822 4077.00 Circle (Radius: 100.00)
CD4-NE3A (LL) T4 110822 4187.00 Circle (Radius: 100.00)
CD4-NE3A (LL) T5 110822 4200.00 Circle (Radius: 100.00)
CD4-NE3A (LL) T6 110822 4245.00 Circle (Radius: 100.00)
CD4-NE3A (LL) T8 110822 4368.00 Circle (Radius: 100.00)
CD4-NE3A (LL) T2 110822 4111.00 Circle (Radius: 100.00)
CD4-NE3A (LL) T3 110822 4150.00 Circle (Radius: 100.00)
CD4-NE3A (LL) T7 110822 4247.00 Circle (Radius: 100.00)
CD4-NE3A T1 QM 4077.00 Circle (Radius: 1320.00)
CD4-NE3A T6 QM 4245.00 Circle (Radius: 1320.00)
CD4-NE3A T8 QM 4368.00 Circle (Radius: 1320.00)
CD4-586wp06.1 Surface Location
CD4-586wp06.1 Surface Location
CD4-586wp06.1 Surface Casing
CD4-586wp06.1 Surface Casing
CD4-586wp06.1 Intermediate Casing 1
CD4-586wp06.1 Intermediate Casing 1
CD4-586wp06.1 Intermediate Casing 2
CD4-586wp06.1 Intermediate Casing 2
CD4-586wp06.1 Top Lefty Production
CD4-586wp06.1 Top Lefty Production
CD4-586wp06.1 TD
CD4-586wp06.1 TD
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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:Nagel, Matt B
To:Guhl, Meredith D (OGC)
Cc:Loepp, Victoria T (OGC); Roby, David S (OGC)
Subject:RE: [EXTERNAL]CRU CD4-586 Permit Review
Date:Tuesday, June 27, 2023 4:14:03 PM
Attachments:image001.png
Hi Meredith.
The correct location for 4B is:
X - 378447
Y - 5957591
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Tuesday, June 27, 2023 3:55 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: [EXTERNAL]CRU CD4-586 Permit Review
Hi Matt,
There seems to be an issue with the coordinates provided in box 4b and also on page 4.
When I input the coordinates into the AOGCC database and check them against the surface coordinates in box 4a, the 4b coordinates are more than +|- 10’ off, as denoted by the
yellow boxes below:
Can someone please recheck the surface hole coordinates in box 4a and 4b?
Thank you,
Meredith
From: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Tuesday, June 27, 2023 2:35 PM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: [EXTERNAL]CRU CD4-586 Permit Review
Hi Meredith.
I apologize. Looks like I accidentally left the plat out of the permit pack.
Please see the attached plat for CD4-586. Let me know if this has all the information you are looking for.
Thanks
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Tuesday, June 27, 2023 2:23 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: [EXTERNAL]CRU CD4-586 Permit Review
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.
Hello Matt,
I’m working on reviewing the permit to drill for CRU CD4-586 and have a request. Could you have someone at ConocoPhillips Alaska plot a map showing leases, proposed CD4-586 well
trace, and completed CD4 well traces, please? Just interested in the completed Narwhal CD4 wells, if that makes it easier.
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s).
It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without
first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov.
PIKKA UNIT
COLVILLE RIVER UNIT
2
36
4
17
24
34
27
6
13
3
25
32
2120
16
31
30
19
18
28
22
15
1
5
29
33T11N, R4E, UMT11N, R5E, UMT10N, R4E, UMT10N, R5E, UMT10N, R5E, UM
T11N, R5E, UMCD2-57CD1-49CD4-24CD4
-
3
0
6CD4-9
3 CD1
-
4
8
CD4-208APB1CD4-214CD2
-53CD2-
2
7
CD2-77CD4-320PB1C
D
1
-
4
8
A
CD4-211
CD4-302
CD4-291PB1CD4-292CD4-291CD4-209NANUQ 5CD4-290CD4-320CD4
-
4
9
9 CD4-289CD4-298PB1
C
D
4
-
5
9
4
P
H
1CD4-301ACD4-298CD4-301C
D
4
-
5
9
5
P
H
CD4-03CD4-208ACD4-301BCD4-597CD4-595CD4
-
5
9
4
ADL388902
ADL372097
ADL392981
ADL380077
ADL391587
ADL393167
ADL392975
ADL393166
ADL384209
ADL372096
ADL392961
ADL380075
ADL380081
ADL380044
ADL388903
ADL384211
ADL380082
ADL384210
ADL391590
ADL393168
ADL380079
CD4
k
5/2/2023
S:\ANC\Longterm\AK GIS\WNS\DM\CRU_Wells\CD4\CD4_586\CD4-586_PTD_PRO\
CD4-586
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 CD4-586
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
X
CRU CD4-586
X
NARWHAL UNDEFINED OIL
223-046
X
COLVILLE RIVER
WELL PERMIT CHECKLIST
Company ConocoPhillips Alaska, Inc.
Well Name:COLVILLE RIV UNIT CD4-586
Initial Class/Type DEV / 1-OIL GeoArea 890 Unit 50360 On/Off Shore On
Program DEVField & Pool Well bore seg
Annular DisposalPTD#:2230460
COLVILLE RIVER, NARWHL UND OIL - 120176
NA1Permit fee attached
Yes Surf Loc: ADL0384211; Portion of Well Passes Thru ADL0380082; TPI in ADL0380081; TD in ADL0391587.2 Lease number appropriate
Yes3Unique well name and number
No COLVILLE RIVER, NARWHAL UNDEFINED OIL4Well located in a defined pool
Yes 551' from Pikka Unit Boundary5Well located proper distance from drilling unit boundary
Yes6Well located proper distance from other wells
Yes7Sufficient acreage available in drilling unit
Yes8If deviated, is wellbore plat included
Yes9Operator only affected party
Yes10Operator has appropriate bond in force
Yes11Permit can be issued without conservation order
Yes12Permit can be issued without administrative approval
Yes13Can permit be approved before 15-day wait
NA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For
NA15All wells within 1/4 mile area of review identified (For service well only)
NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)
NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)
Yes 120'18 Conductor string provided
Yes SC set @ 2748' MD19Surface casing protects all known USDWs
Yes20CMT vol adequate to circulate on conductor & surf csg
No21CMT vol adequate to tie-in long string to surf csg
No Completed with uncemented liner with frac sleeves22CMT will cover all known productive horizons
Yes23Casing designs adequate for C, T, B & permafrost
Yes Rig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pit
NA25If a re-drill, has a 10-403 for abandonment been approved
Yes Anti-collision analysis complete; no major risk failures26Adequate wellbore separation proposed
Yes Diverter waiver approved per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulations
Yes Max formation pressure is 1922 psig(9.1 ppg EMW); will drill w/ 8.6-10.5 ppg EMW28Drilling fluid program schematic & equip list adequate
Yes29BOPEs, do they meet regulation
Yes MPSP is 1922 psig; will test BOPs to 5000 psig initial and 3500 psig subsequent30BOPE press rating appropriate; test to (put psig in comments)
Yes31Choke manifold complies w/API RP-53 (May 84)
Yes32Work will occur without operation shutdown
No33Is presence of H2S gas probable
NA34Mechanical condition of wells within AOR verified (For service well only)
Yes None anticipated based on nearby wells in the Narwhal Sand.35 Permit can be issued w/o hydrogen sulfide measures
Yes Narwhal Central and Lefty sands are expected to be overpressured to ~8.9 ppg for Central36Data presented on potential overpressure zones
NA and ~9.6 ppg for Lefty EMW. MPD will be used in combo with ~10 ppg mud to mitigate any37Seismic analysis of shallow gas zones
NA overpressured intervals and to maintain wellbore stability. Interm2 section may also use MPD along with38Seabed condition survey (if off-shore)
NA 9.6 ppg mud for instability.39 Contact name/phone for weekly progress reports [exploratory only]
Appr
MDG
Date
6/28/2023
Appr
VTL
Date
6/28/2023
Appr
MDG
Date
6/28/2023
Administration
Engineering
Geology
Geologic
Commissioner:Date:Engineering
Commissioner:Date Public
Commissioner Date
JLC 6/28/2023
